FERC Form

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

NOTES TO FINANCIAL STATEMENTS

Use the space below for important notes regarding the Balance Sheet, Statement of Income for the year, Statement of Retained Earnings for the year, and Statement of Cash Flows, or any account thereof. Classify the notes according to each basic statement, providing a subheading for each statement except where a note is applicable to more than one statement.
Furnish particulars (details) as to any significant contingent assets or liabilities existing at end of year, including a brief explanation of any action initiated by the Internal Revenue Service involving possible assessment of additional income taxes of material amount, or of a claim for refund of income taxes of a material amount initiated by the utility. Give also a brief explanation of any dividends in arrears on cumulative preferred stock.
For Account 116, Utility Plant Adjustments, explain the origin of such amount, debits and credits during the year, and plan of disposition contemplated, giving references to Commission orders or other authorizations respecting classification of amounts as plant adjustments and requirements as to disposition thereof.
Where Accounts 189, Unamortized Loss on Reacquired Debt, and 257, Unamortized Gain on Reacquired Debt, are not used, give an explanation, providing the rate treatment given these items. See General Instruction 17 of the Uniform System of Accounts.
Give a concise explanation of any retained earnings restrictions and state the amount of retained earnings affected by such restrictions.
If the notes to financial statements relating to the respondent company appearing in the annual report to the stockholders are applicable and furnish the data required by instructions above and on pages 114-121, such notes may be included herein.
For the 3Q disclosures, respondent must provide in the notes sufficient disclosures so as to make the interim information not misleading. Disclosures which would substantially duplicate the disclosures contained in the most recent FERC Annual Report may be omitted.
For the 3Q disclosures, the disclosures shall be provided where events subsequent to the end of the most recent year have occurred which have a material effect on the respondent. Respondent must include in the notes significant changes since the most recently completed year in such items as: accounting principles and practices; estimates inherent in the preparation of the financial statements; status of long-term contracts; capitalization including significant new borrowings or modifications of existing financing agreements; and changes resulting from business combinations or dispositions. However were material contingencies exist, the disclosure of such matters shall be provided even though a significant change since year end may not have occurred.
Finally, if the notes to the financial statements relating to the respondent appearing in the annual report to the stockholders are applicable and furnish the data required by the above instructions, such notes may be included herein.

The notes presented herein were derived from the notes disclosed within the Annual Report of the Exelon Corporation (Exelon) on Form 10-K for the fiscal year ended December 31, 2023. The notes presented herein were modified to include information relevant to Commonwealth Edison Company (ComEd). All amounts presented within the footnotes are rounded in millions unless otherwise noted.

1. Significant Accounting Policies

Description of Business

ComEd was organized in the State of Illinois in 1913 as a result of the merger of Cosmopolitan Electric Company into the original corporation named Commonwealth Edison Company, which was incorporated in 1907. ComEd is engaged principally in the purchase and regulated retail sale of electricity and the provision of distribution and transmission services to a diverse base of residential, commercial, industrial and wholesale customers in Northern Illinois, including the City of Chicago. ComEd’s retail service territory has an area of approximately 11,450 square miles and an estimated population of 9.2 million. The service territory includes the City of Chicago, an area of about 225 square miles with an estimated population of 2.6 million. ComEd has approximately 4.1 million customers.

Basis of Presentation

ComEd is a principal indirect subsidiary of Exelon, which owns more than 99% of ComEd’s common stock.

Accounting policies for regulated operations are in accordance with those prescribed by the regulatory authorities having jurisdiction, principally the Illinois Commerce Commission (ICC) under state public utility laws and the Federal Energy Regulatory Commission (FERC). The accompanying financial statements have been prepared in accordance with the accounting requirements of FERC as set forth in the Uniform System of Accounts (USOA) and accounting releases, which differ from accounting principles generally accepted in the United States (GAAP). The principal differences from GAAP include the exclusions of current maturities of long-term debt from current liabilities, the exclusion of debt issuance costs from long-term debt, the requirement to report deferred tax assets and liabilities separately rather than as a single amount, the classification of accrued taxes as assets and liabilities rather than a net amount, the exclusion of FIN 48 liabilities related to temporary income tax differences, the derecognition of operating leases from the balance sheet, the classification of cloud computing costs, and the classification of certain other assets and liabilities as current instead of noncurrent.

ComEd’s investments in Commonwealth Edison Company of Indiana, Inc. (ComEd of Indiana), RITELine Illinois, LLC and EdiSun, LLC are accounted for under the equity method of accounting in accordance with the USOA. These entities are consolidated in ComEd’s GAAP financial statements.

ComEd’s investment in ComEd Financing III is accounted for under the equity method of accounting in accordance with the USOA. This entity is not consolidated in ComEd’s GAAP financial statements.

COVID-19

ComEd has taken steps to mitigate the potential risks posed by the global outbreak (pandemic) of the 2019 novel coronavirus (COVID-19). ComEd provides a critical service to its customers and has taken measures to keep employees who operate the business safe and minimize unnecessary risk of exposure to the virus, including extra precautions for employees who work in the field. ComEd has implemented work from home policies where appropriate.

Management makes estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities as of the date of the financial statements and accompanying notes, and the amounts of revenues and expenses reported during the periods covered by those financial statements and accompanying notes. As of December 31, 2023 and 2022, and through the date of the report, management assessed certain accounting matters that require consideration of forecasted financial information, including, but not limited to, our accumulated provision for uncollectible accounts and the carrying value of goodwill and other long-lived assets, in context with the information reasonably available and the unknown future impacts of COVID-19. ComEd's future assessment of the magnitude and duration of COVID-19, as well as other factors, could result in material impacts to the financial statements in future reporting periods.

Use of Estimates

The preparation of financial statements in conformity with USOA requires management to make estimates and assumptions that affect the amounts reported in the financial statements and accompanying notes. Areas in which significant estimates

have been made include, but are not limited to, the accounting for pension and other postretirement benefits (OPEB), unbilled energy revenues, allowance for uncollectible accounts, inventory reserves, goodwill, and long-lived asset impairments, derivative instruments, fixed asset depreciation, environmental costs and other loss contingencies, asset retirement obligations (AROs), and taxes. Actual results could differ from those estimates.

Regulatory Accounting

For its regulated electric operations, ComEd reflects the effects of cost-based rate regulation in its financial statements, which is required for entities with regulated operations that meet the following criteria: 1) rates are established or approved by a third-party regulator; (2) rates are designed to recover the entities’ cost of providing services or products; and (3) there is a reasonable expectation that rates designed to recover costs can be charged to and collected from customers. ComEd accounts for their regulated operations in accordance with regulatory and legislative guidance from the regulatory authority having jurisdiction, principally the ICC, under state public utility laws and the FERC under various Federal laws. Regulatory assets and liabilities are amortized and the related expense or revenue is recognized in the Statement of Income consistent with the recovery or refund included in customer rates. ComEd's regulatory assets and liabilities as of the balance sheet date are probable of being recovered or settled in future rates. If a separable portion of ComEd's business was no longer able to meet the criteria discussed above, ComEd would be required to eliminate from its financial statements the effects of regulation for that portion, which could have a material impact on its financial statements. See Note 2—Regulatory Matters for additional information.

ComEd treats the impacts of a final rate order received after the balance sheet date but prior to the issuance of the financial statements as a non-recognized subsequent event, as the receipt of a final rate order is a separate and distinct event that has future impacts on the parties affected by the order.

Revenues

Operating Revenues. ComEd’s operating revenues generally consist of revenues from contracts with customers involving the sale and delivery of power, utility revenues from alternative revenue programs (ARP), and realized and unrealized revenues recognized under mark-to-market energy commodity derivative contracts. ComEd recognizes revenue from contracts with customers to depict the transfer of goods or services to customers in an amount that the entities expect to be entitled to in exchange for those goods or services. ComEd's primary sources of revenue include regulated electric tariff sales, distribution and transmission services. At the end of each month, the ComEd accrues an estimate for the unbilled amount of energy delivered or services provided to customers.

ComEd records ARP revenue for its best estimate of the electric distribution, energy efficiency, distributed generation rebates, and transmission revenue impacts resulting from future changes in rates that ComEd believes are probable of approval by the ICC and FERC in accordance with its formula rate mechanisms. See Note 2—Regulatory Matters for additional information.

Taxes Directly Imposed on Revenue-Producing Transactions. ComEd collects certain taxes from customers such as sales and gross receipts taxes, along with other taxes, surcharges and fees, that are levied by state or local governments on the sale or distribution of electricity. Some of these taxes are imposed on the customer, but paid by ComEd, while others are imposed on ComEd. Where these taxes are imposed on the customer, such as sales taxes, they are reported on a net basis with no impact to the Statement of Income. However, where these taxes are imposed on ComEd, such as gross receipts taxes or other surcharges or fees, they are reported on a gross basis. Accordingly, revenues are recognized for the taxes collected from customers along with an offsetting expense. See Note 14— Supplemental Financial Information for ComEd’s utility taxes that are presented on a gross basis.

Income Taxes

Deferred federal and state income taxes are recorded on significant temporary differences between the book and tax basis of assets and liabilities and for tax benefits carried forward. Investment tax credits have been deferred in ComEd's Balance Sheets and are recognized in book income over the life of the related property. In accordance with USOA, ComEd reports deferred income tax balances arising from temporary differences in Accounts 190, 282 and 283 as appropriate, which differs from the net presentation required by GAAP. See Note 7—Income Taxes for additional information. ComEd recognizes accrued interest related to unrecognized tax benefits in interest expense or interest income in Net Interest Charges and Other Income, respectively on its Statements of Income.

ComEd accounts for uncertain income tax positions using a benefit recognition model with a two-step approach; a more-likely-than-not recognition criterion; and a measurement approach that measures the position as the largest amount of tax benefit that is greater than 50% likely of being realized upon ultimate settlement. If it is not more-likely-than-not that the benefit of the tax position will be sustained on its technical merits, no benefit is recorded. Uncertain tax positions that relate only to timing of when an item is included on a tax return are considered to have met the recognition threshold.

ComEd accounts for uncertain income tax positions in accordance with FERC's guidance on Accounting and Financial Reporting for Uncertainty in Income Taxes, issued in Docket No. AI07-2-000 for FERC reporting purposes. The guidance requires, among other things, that entities should continue to recognize deferred income taxes for FERC accounting and reporting purposes based on the difference between positions taken in tax returns filed or expected to be filed and amounts reported in financial statements.

Cash and Cash Equivalents

ComEd considers investments purchased with an original maturity of three months or less to be cash equivalents.

Restricted Cash and Cash Equivalents

Restricted cash and cash equivalents represent funds that are restricted to satisfy designated current liabilities. As of December 31, 2023 and 2022, ComEd’s restricted cash and cash equivalents primarily represented cash collateral held from suppliers associated with ComEd’s energy and renewable energy credits (REC) procurement contracts, any over-recovered Renewable Energy Portfolio Standards (RPS) costs and alternative compliance payments received from Retail Electric Suppliers (RES) pursuant to the Future Energy Jobs Act (FEJA), and costs for the remediation of a Manufactured Gas Plant (MGP) site.

Restricted cash and cash equivalents not available to satisfy current liabilities are classified as noncurrent assets. As of December 31, 2020 and 2019, ComEd's noncurrent restricted cash and cash equivalents primarily represented over-recovered RPS costs and alternative compliance payments received from RES pursuant to FEJA and costs for the remediation of an MGP site.

Accumulated Provision for Uncollectible Accounts on Accounts Receivables

The accumulated provision for uncollectible accounts reflects ComEd's best estimate of losses on the customers' accounts receivable balances based on historical experience, current information, and reasonable and supportable forecasts.

The accumulated provision for uncollectible accounts for ComEd's customers is developed by applying ComEd's loss rates, based on historical loss experience, current conditions, and forward looking risk factors, to the outstanding receivable balance by customer risk segment. ComEd's customer accounts are written off consistent with approved regulatory requirements. Adjustments to the accumulated provision for uncollectible accounts are primarily recorded to Operating and maintenance expense on ComEd's Statement of Income or Regulatory assets and liabilities on ComEd's Balance Sheet. See Note 2 — Regulatory Matters for additional information regarding the regulatory recovery of uncollectible accounts expense on customers' accounts receivable.

ComEd has certain non-customer receivables in Other deferred debits and other assets which primarily are with governmental agencies and other high-quality counterparties with no history of default. As such, the accumulated provision for uncollectible accounts related to these receivables is not material. ComEd monitors these balances and will record an allowance if there are indicators of a decline in credit quality. See Note 3 — Accounts Receivable for additional information.

Inventories

Inventory is recorded at the lower of weighted average cost or net realizable value. Provisions are recorded for excess and obsolete inventory. Materials and supplies are generally included in inventory when purchased. Materials and supplies inventory generally includes transmission and distribution materials and are expensed to Operating and maintenance or capitalized to Property, plant, and equipment, as appropriate, when installed or used.

Property, Plant and Equipment

Property, plant and equipment is recorded at original cost. Original cost includes construction-related direct labor and material costs and indirect construction costs including labor and related costs of departments associated with supporting construction activities. When appropriate, original cost also includes allowance for funds used during construction (AFUDC) for regulated property. The cost of repairs and maintenance and minor replacements of property is charged to Operating and maintenance expense as incurred.

Third parties reimburse ComEd for all or a portion of expenditures for certain capital projects. Such contributions in aid of construction costs (CIAC) are recorded as a reduction to Property, plant and equipment, net.

Upon retirement, the cost of property, net of salvage, is charged to accumulated depreciation consistent with the composite and group methods of depreciation. Depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement. Actual incurred removal costs are applied against a related regulatory liability or recorded to a regulatory asset if in excess of previously collected removal costs.

Capitalized Software. Certain costs, such as design, coding, and testing incurred during the application development stage of software projects that are internally developed or purchased for operational use are capitalized within Property, plant, and equipment. Similar costs incurred for cloud-based solutions treated as service arrangements are capitalized within Property, plant, and equipment. Such capitalized amounts are amortized ratably over the expected lives of the projects when they become operational, generally not to exceed five years. Certain other capitalized software costs are being amortized over longer lives, based on the expected life or pursuant to prescribed regulatory requirements.

Allowance for Funds Used During Construction (AFUDC). AFUDC is the cost, during the period of construction, of debt and equity funds used to finance construction projects for regulated operations. AFUDC is recorded to construction work in progress and as a non-cash credit to an allowance that is included in interest expense for debt-related funds and other income and deductions for equity-related funds. The rates used for capitalizing AFUDC are computed under a method prescribed by regulatory authorities.

See Note 4 — Property, Plant, and Equipment for additional information.

Depreciation and Amortization

Depreciation is generally recorded over the estimated service lives of property, plant and equipment on a straight-line basis using the group, composite, or unitary methods of depreciation. The group approach is typically for groups of similar assets that have approximately the same useful lives and the composite approach is used for dissimilar assets that have different lives. Under both methods, a reporting entity depreciates the assets over the average life of the assets in the group. ComEd's depreciation expense includes the estimated cost of dismantling and removing plant from service upon retirement, which is consistent with ComEd's regulatory recovery method. The estimated service lives for ComEd are based on a combination of depreciation studies, historical retirements, site licenses, and management estimates of operating costs and expected future energy market conditions. See Note 4 — Property, Plant, and Equipment for additional information regarding depreciation.

Amortization of regulatory assets and liabilities is recorded over the recovery or refund period specified in the related legislation or regulatory order or agreement. When the recovery or refund period is less than one year, amortization is recorded to the line item in which the deferred cost or income would have originally been recorded in ComEd's Statement of Income. Amortization of ComEd’s electric distribution and energy efficiency formula rate regulatory assets and ComEd’s transmission formula rate regulatory asset is recorded to Operating revenues.

Amortization of income tax related regulatory assets and liabilities is generally recorded to Income tax expense. Except for the regulatory assets and liabilities discussed above, amortization is generally recorded to Depreciation and amortization in ComEd's Statement of Income when the recovery period is more than one year.

See Note 2 — Regulatory Matters for additional information regarding the amortization of ComEd’s regulatory assets and liabilities.

Asset Retirement Obligations

ComEd updates its AROs either annually or on a rotational basis at least once every three years, based on a risk profile, unless circumstances warrant more frequent updates. The updates factor in new cost estimates, credit-adjusted, risk-free rates (CARFR) and escalation rates, and the timing of cash flows. AROs are accreted throughout each year to reflect the time value of money for these present value obligations through an increase to regulatory assets. See Note 5 — Asset Retirement Obligations for additional information.

Guarantees

If necessary, ComEd recognizes a liability at the time of issuance of a guarantee for the fair value of the obligations it has undertaken by issuing the guarantee.

The liability is reduced or eliminated as ComEd is released from risk under the guarantee. Depending on the nature of the guarantee, ComEd's release from risk may be recognized only upon the expiration or settlement of the guarantee or by a systematic and rational amortization method over the term of the guarantee. See Note 12—Commitments and Contingencies for additional information.

Asset Impairments

Long-Lived Assets. ComEd evaluates the carrying value of its long-lived assets for recoverability whenever events or changes in circumstances indicate that the carrying value of those assets may not be recoverable. Indicators of impairment may include specific regulatory disallowance, abandonment, or plans to dispose of a long-lived asset significantly before the end of its useful life. When the estimated undiscounted future cash flows attributable to the long-lived asset may not be

recoverable, the amount of the impairment loss is determined by measuring the excess of the carrying amount of the long-lived asset over its fair value.

Goodwill. Goodwill represents the excess of the purchase price paid over the estimated fair value of the net assets acquired and liabilities assumed in the acquisition of a business. Goodwill is not amortized but is assessed for impairment at least annually or on an interim basis if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. See Note 6 - Intangible Assets for additional information.

Derivative Financial Instruments

All derivatives are recognized on the balance sheet at their fair value unless they qualify for certain exceptions, including the normal purchases and normal sales (NPNS) exception. For derivatives intended to serve as economic hedges, changes in fair value are recognized in earnings each period. Amounts classified in earnings are included in Operating revenue, Purchased power, Interest expense, or Other, net in the Statement of Income based on the activity the transaction is economically hedging. While the majority of the derivatives serve as economic hedges, there are also derivatives entered into for proprietary trading purposes, subject to ComEd's Risk Management Policy, and changes in the fair value of those derivatives are recorded in revenue in the Statement of Income. At ComEd, changes in fair value may be recorded as a regulatory asset or liability if there is an ability to recover or return the associated costs. Cash inflows and outflows related to derivative instruments are included as a component of operating, investing or financing cash flows in the Statement of Cash Flows, depending on the nature of each transaction.

NPNS are contracts where physical delivery is probable, quantities are expected to be used or sold in the normal course of business over a reasonable period and will not be financially settled. Revenues and expenses on derivative contracts that qualify, and are designated, as NPNS are recognized when the underlying physical transaction is completed. While these contracts are considered derivative financial instruments, they are not required to be recorded at fair value. See Note 9 - Derivative Financial Instruments for additional information.

Retirement Benefits

ComEd participates in Exelon’s defined benefit pension plans and OPEB plans.

The plan obligations and costs of providing benefits under these plans are measured as of December 31. The measurement involves various factors, assumptions and accounting elections. The impact of assumption changes or experience different from that assumed on pension and OPEB obligations is recognized over time rather than immediately recognized in the Statement of Income. Gains or losses in excess of the greater of ten percent of the projected benefit obligation or the market-related value of plan assets are amortized over the expected average remaining service period of plan participants. See Note 8— Retirement Benefits for additional information.

New Accounting Pronouncements

New Accounting Standards Issued and Not Yet Adopted as of December 31, 2023

The following new authoritative accounting guidance issued by the FASB has not yet been adopted and reflected by ComEd in their financial statements as of December 31, 2023. Unless otherwise indicated, ComEd is currently assessing the impacts such guidance may have (which could be material) in their Balance Sheet, Statement of Income, Statement of Cash Flows and disclosures, as well as the potential to early adopt where applicable. ComEd has assessed other FASB issuances of new standards which are not listed below given the current expectation that such standards will not significantly impact ComEd's financial reporting.

Improvement to Income Tax Disclosures (Issued December 2023). Provides additional disclosure requirements related to the effective tax rate reconciliation and income taxes paid. Under the revised guidance for the effective tax reconciliations, entities would be required to disclose: (1) eight specific categories in the effective tax rate reconciliation in both percentages and reporting currency amount, (2) additional information for reconciling items over a certain threshold, (3) explanation of individual reconciling items disclosed, and (4) provide a qualitative description of the state and local jurisdictions that contribute to the majority of the state income tax expense. For each annual period presented, the new standard requires disclosure of the year-to-date amount of income taxes paid (net of refunds received) disaggregated by federal, state, and foreign. It also requires additional disaggregated information on income taxes paid (net of refunds received) to an individual jurisdiction equal to or greater than 5% of total income taxes paid (net of refunds received). The standard is effective January 1, 2025, with early adoption permitted.

2. Regulatory Matters

The following matters below discuss the status of material regulatory and legislative proceedings of ComEd.

Distribution Base Rate Case Proceedings

The following tables show the completed and pending distribution base rate case proceedings in 2023.

Completed Distribution Base Rate Case Proceedings


Jurisdiction	Filing Date	Service	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase		Approved ROE		Approval Date	Rate Effective Date
Illinois	April 15, 2022(a)	Electric	$	199	$	199	7.85	%	November 17, 2022	January 1, 2023
	January 17, 2023(b)		$	1,487	$	501	8.905	%	December 14, 2023	January 1, 2024
	April 21, 2023(c)		$	247	$	259	8.91	%	November 30, 2023	January 1, 2024

__________

(a) ComEd’s 2023 approved revenue requirement above reflects an increase of $144 million for the initial year revenue requirement for 2023 and an increase of $55 million related to the annual reconciliation for 2021. The revenue requirement for 2023 provides for a weighted average debt and equity return on distribution rate base of 5.94% inclusive of an allowed ROE of 7.85%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The reconciliation revenue requirement for 2021 provides for a weighted average debt and equity return on distribution rate base of 5.91%, inclusive of an allowed ROE of 7.78%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points less a performance metrics penalty of 7 basis points. ComEd's last performance-based electric distribution formula rate update filing under EIMA was completed in 2022. See discussion of CEJA below for details on the transition away from the electric distribution formula rate.

(b) Reflects a four-year cumulative multi-year rate plan for January 1, 2024 to December 31, 2027. On December 14, 2023, the ICC approved year-over-year distribution revenue requirement increases in 2024-2027, with an amendatory order on January 10, 2024, of approximately $451 million effective January 1, 2024, $14 million effective January 1, 2025, $6 million effective January 1, 2026, and $30 million effective January 1, 2027, based on an ROE of 8.905%, an equity ratio of 50%, and year end 2022 rate base. The ICC rejected ComEd’s Grid Plan, requiring ComEd to file a revised Grid Plan by March 13, 2024, 90 days after the issuance of the December final order. The ICC also directed that the revised Grid Plan would be reviewed through further formal proceedings in that docket. On January 10, 2024, the ICC granted one portion of ComEd’s application for rehearing of the December 14, 2023 final order, and directing that a 150-day rehearing process reconsider the revenue requirements for the test years (2024-2027), absent an approved Grid Plan. On January 31,2024, the ICC further clarified the scope of the rehearing process. ComEd anticipates that the revenue requirements determined during the rehearing process will be further updated upon approval of a revised Grid Plan. On January 10, 2024, ComEd also filed with the Illinois appellate court an appeal of various aspects of the ICC’s final order on which rehearing was denied, including the 8.905% ROE, 50% equity ratio, and denial of any return on ComEd’s pension asset. On March 13, 2024, ComEd filed its revised Grid Plan with supporting testimony and schedules with the ICC. On March 15, 2024, ComEd filed a petition to adjust its MRP to authorize increased rates consistent with the March 13 refiled Grid Plan.

(c) On November 30, 2023, the Delivery Reconciliation Amount for 2022 defined in Rider Delivery Service Pricing Reconciliation (Rider DSPR) was approved. The delivery reconciliation amount allows for the reconciliation of the revenue requirement in effect in the final years in which formula rates are determined and until such time as new rates are established under ComEd’s approved MRP. The 2023 filing reconciled the delivery service rates in effect in 2022 with the actual delivery service costs incurred in 2022. The reconciliation revenue requirement provides for a weighted average debt and equity return on distribution rate base of 6.48%, inclusive of an allowed ROE of 8.91%, reflecting the monthly yields on 30-year treasury bonds plus 580 basis points.

Transmission Formula Rates

ComEd’s transmission rate is established based on a FERC-approved formula. ComEd is required to file an annual update to the FERC-approved formula on or before May 15, with the resulting rate effective on June 1 of the same year. The annual update is based on prior year actual costs and current year projected capital additions (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect beginning June 1 of the prior year and actual costs incurred for that year (annual reconciliation).

For 2023, the following total increases/(decreases) was included in ComEd’s electric transmission formula rate update:


Filing Date(a)	Initial Revenue Requirement Increase		Annual Reconciliation Decrease		Total Revenue Requirement Increase		Allowed Return on Rate Base(b)		Allowed ROE(c)
May 12, 2023	$	20	$	63	$	83	8.09	%	11.50	%

__________

(a)All rates are effective June 1, 2023 - May 31, 2024, subject to review by interested parties pursuant to review protocols of ComEd's tariff.

(b)Represents the weighted average debt and equity return on transmission rate bases. The common equity component of the ratio used to calculate the weighted average debt and equity return on the transmission formula rate base is currently capped at 55%.

(c)The rate of return on common equity includes a 50-basis-point incentive adder for being a member of a RTO.

Other State Regulatory Matters

Illinois Regulatory Matters

Clean and Equitable Jobs Act (CEJA). On September 15, 2021, the Governor of Illinois signed into law CEJA. CEJA includes, among other features, (1) procurement of CMCs from qualifying nuclear-powered generating facilities, (2) a requirement to file a general rate case or a new four-year MRP no later than January 20, 2023 to establish rates effective after ComEd’s existing performance-based distribution formula rate sunsets, (3) requirements that ComEd and the ICC initiate and conduct various regulatory proceedings on subjects including ethics, spending, grid investments, and performance metrics.

ComEd Electric Distribution Rates

ComEd filed, and received approval for, its last performance-based electric distribution formula rate update under EIMA in 2022; those rates were in effect throughout 2023.

On February 3, 2022, the ICC approved a tariff that establishes the process under which ComEd reconciled its 2022 and will reconcile its 2023 rate year revenue requirements with actual costs. Those reconciliation amounts are determined using the same process used for prior reconciliations under the performance-based electric distribution formula rate. Using that process, for the rate years 2022 and 2023 ComEd will ultimately collect revenues from customers reflecting each year’s actual recoverable costs, year-end rate base, and a weighted average debt and equity return on distribution rate base, with the ROE component based on the annual average of the monthly yields of the 30-year U.S. Treasury bonds plus 580 basis points. In April 2023, ComEd filed its first petition with the ICC to reconcile its 2022 actual costs with the approved revenue requirement that was in effect in 2022; the final order was issued on November 30, 2023, for rates beginning January 2024. In 2024, ComEd will file with the ICC its 2023 actual costs with the approved revenue requirement that was in effect in 2023.

Beginning in 2024, ComEd will recover from retail customers, subject to certain exceptions, the costs it incurs to provide electric delivery services either through its electric distribution rate or other recovery mechanisms authorized by CEJA. On January 17, 2023, ComEd filed a petition with the ICC seeking approval of a MRP for 2024-2027. The MRP supports a multi-year grid plan (Grid Plan), also filed on January 17, covering planned investments on the electric distribution system within ComEd’s service area through 2027. Costs incurred during each year of the MRP are subject to ICC review and the plan’s revenue requirement for each year will be reconciled with the actual costs that the ICC determines are prudently and reasonably incurred for that year. The reconciliation is subject to adjustment for certain costs, including a limitation on recovery of costs that are more than 105% of certain costs in the previously approved MRP revenue requirement, absent a modification of the rate plan itself. Thus, for example, the rate adjustments necessary to reconcile 2024 revenues to ComEd’s actual 2024 costs incurred would take effect in January 2026 after the ICC’s review during 2025. On May 22, 2023, direct testimony was filed by ICC staff and more than a dozen intervenors and intervenor groups. The testimonies addressed a wide variety of topics, including rate of return on equity, capital structure, grid planning, various distribution grid and information technology investments, and affordability and customer service. ComEd also made voluntary adjustments and, per the ICC’s final beneficial electrification order requiring ComEd to recover beneficial electrification costs through the MRP, increased its total revenue requirement request from $1.472 billion to $1.545 billion. ComEd filed its reply brief on September 27, 2023, to adjust its total requested revenue requirement increase to $1.487 billion.

On December 14, 2023, the ICC issued a final order. The ICC rejected ComEd’s Grid Plan as non-compliant with certain requirements of CEJA, and required ComEd to file a revised Grid Plan by March 13, 2024, 90 days after the issuance of the final order. In the absence of an approved Grid Plan, the ICC set ComEd’s forecast revenue requirements for 2024-2027 based on ComEd's approved year-end 2022 rate base. This results in a total cumulative revenue requirement increase of $501 million, a $986 million total revenue reduction from the requested cumulative revenue requirement increase but remains subject to annual reconciliation in accordance with CEJA. The final order approved the process and formulas associated with the MRP reconciliation mechanisms. The ICC did not approve a previously proposed phase-in of the ICC's approved year-over-year revenue increases, and it also denied ComEd's ability to earn a return on its pension asset.

On December 22, 2023, ComEd filed an application for rehearing on several findings in the final order including the use of the 2022 year-end rate base to establish forecast revenue requirements for 2024-2027, ROE, pension asset return, and capital structure. On January 10, 2024, ComEd’s application for rehearing was denied on all issues except for the order’s use of the 2022 year-end rate base. On January 31, 2024, the ICC granted ComEd's motion seeking additional clarification on the scope on rehearing, generally accepting ComEd's proposal and confirming that the rehearing will determine if the forecasted year-end 2023 rate base should be used to set rates for 2024 through 2027 until a refiled Grid Plan is approved. A final rehearing order on that topic is statutorily required by early June 2024. On January 10, 2024, ComEd also filed an appeal in the Illinois Appellate Court of the issues on which rehearing was denied, including but not limited to the allowed ROE and denial of a return on ComEd’s pension asset. There is no deadline by when the appellate court must rule. On March 7, 2024, the ICC

adopted an interim order on scheduling, which confirmed that it intends to issue a final order on ComEd’s refiled Grid Plan by the end of 2024 and that it will implement rates that will go into effect January 1, 2025, inclusive of a Grid Plan. On March 13, 2024, ComEd filed its revised Grid Plan with supporting testimony and schedules with the ICC. The Grid Plan is designed to meet or exceed every requirement identified by the ICC in its December order that rejected ComEd’s initial Grid Plan. On March 15, 2024, ComEd filed a petition to adjust its MRP to authorize increased rates consistent with the March 13 refiled Grid Plan. ComEd has completed and placed in service additional utility plant assets in 2023 and 2024 and will continue to complete and place in service additional utility plant assets prior to the approval of the new Grid Plan. There are still significant unknowns, but ComEd does not currently believe that it is probable that the initially uncollected depreciation or return on the recently completed plant will ultimately be disallowed.

In January 2022, ComEd filed a request with the ICC proposing performance metrics that would be used in determining ROE incentives and penalties in the event ComEd filed a MRP in January 2023. On September 27, 2022, the ICC issued a final order approving seven performance metrics that provide symmetrical performance adjustments of 32 total basis points to ComEd’s rate of return on common equity based on the extent to which ComEd achieves the annual performance goals. On November 10, 2022, the ICC granted ComEd's application for rehearing, in part. On April 5, 2023, the ICC issued its final order on rehearing for the performance and tracking metrics proceeding, in which the ICC declined to adopt ComEd's proposed modifications to the reliability and peak load reduction performance metrics. Efforts are underway to implement the performance metrics, which took effect on January 1, 2024. ComEd will make its initial filing in 2025 to assess performance achieved under the metrics in 2024, and to determine any ROE adjustment, which would take effect in 2026.

Carbon Mitigation Credit

CEJA establishes decarbonization requirements for Illinois as well as programs to support the retention and development of emissions-free sources of electricity. ComEd is required to purchase CMCs from participating nuclear-powered generating facilities between June 1, 2022 and May 31, 2027. The price to be paid for each CMC was established through a competitive bidding process that included consumer-protection measures that capped the maximum acceptable bid amount and a formula that reduces CMC prices by an energy price index, the base residual auction capacity price in the ComEd zone of PJM, and the monetized value of any federal tax credit or other subsidy if applicable. The consumer protection measures contained in CEJA will result in net payments to ComEd ratepayers if the energy index, the capacity price and applicable federal tax credits or subsidy exceed the CMC contract price. In the June 2022 billing period. ComEd began issuing credits to its retail customers under its new CMC rider. A regulatory asset is recorded for the difference between customer credits issued and the credit to be received from the participating nuclear-powered generating facilities. The balance as of December 31, 2023 is $673 million.

Under CEJA, the costs of procuring CMCs, including carrying costs, are recovered through a rider, the Rider Carbon-Free Resource Adjustment (Rider CFRA). As originally approved by the ICC, Rider CFRA provides for an annual reconciliation and true-up to actual costs incurred or credits received by ComEd to purchase CMCs, with any difference to be credited to or collected from ComEd’s retail customers in subsequent periods. The difference between the net payments to (or receivables from) ComEd ratepayers and the credits received by ComEd to purchase CMCs is recorded to Purchased power expense with an offset to the regulatory asset (or regulatory liability). On December 21, 2022, ComEd filed an amendment to Rider CFRA proposing that it recover costs or provide credits faster than the tariff allows, implement monthly reconciliations, and allow ComEd to adjust Rider CFRA rates based not only on anticipated differences but also past payments or credits, and implement monthly reconciliations beginning with the June 2023 delivery period. The ICC approved the proposal on January 19, 2023. In addition, on March 24, 2023, ComEd submitted revisions to Rider CFRA which clarified the methodology for calculating interest to be included in the annual reconciliation associated with the June 2022 through May 2023 delivery year. The ICC approved the proposal on April 20, 2023. On February 2, 2024, ComEd filed a petition with the ICC to initiate the reconciliation proceeding for the costs incurred in connection with the procurement of CMCs during the delivery year beginning June 1, 2022 and extending through May 31, 2023.

Excess Deferred Income Taxes

The ICC initiated a docket to accelerate and fully credit to customers TCJA unprotected property-related EDIT no later than December 31, 2025. On July 7, 2022, the ICC issued a final order on the schedule for the acceleration of EDIT amortization, adopting the proposal as submitted by several parties, including ComEd, ICC Staff, the Illinois Attorney General's Office, and the Citizens Utility Board. EDIT amortization will be credited to customers through a new rider from January 1, 2023 through December 31, 2025.

Beneficial Electrification Plan

On March 23, 2023, the ICC issued its final order approving the beneficial electrification plan for ComEd. The ICC rejected ComEd's request to treat a large portion of beneficial electrification costs as a regulatory asset and ordered ComEd to seek cost recovery through the multi-year rate plan filing for 2024 and 2025, and the final formula rate reconciliation docket for

2023, rather than through a separate charge. The order also authorized an overall annual budget of $77 million per year for the three-year plan period (2023 through 2025), with flexibility to roll forward unused funds to future years within the same plan period. On April 18, 2023, ComEd filed an application for rehearing in the beneficial electrification plan docket. The Chicago Transit Authority and City of Chicago, jointly, and the Office of the Illinois Attorney General (ILAG) also filed applications for rehearing. On April 27, 2023, ICC staff filed a motion for clarification, seeking clarification from the ICC on the precise budget described in the final order. On May 8, 2023, the ICC denied all applications for rehearing, and entered an amendatory order regarding the annual beneficial electrification plan budgets. ComEd has been directed to use good faith efforts to spend $77 million annually. ComEd subsequently filed its compliance filing in May 2023, detailing project related spending, clarifying the procedure that will be used to seek stakeholder feedback related to beneficial electrification pilot programs, and including the timeline for tariff changes required to implement the programs. ComEd and the ILAG both filed appeals of the ICC’s interim order that addressed the permissible scope of utility beneficial electrification programs outside of transportation and the rate impact cap. The ILAG also filed an appeal seeking reversal of portions of the ICC’s final decision. The final order partly mooted ComEd’s appeal of the interim order and ComEd has decided not to pursue the other issues. As such, ComEd moved to voluntarily dismiss its appeal and the appellate court granted that request. The ILAG consolidated their appeals. Any ruling on the appeals, even a negative ruling removing programs from the BE Plan or lowering the overall budget of the BE Plan, will only impact forward-looking costs.

Energy Efficiency

CEJA extends ComEd’s current cumulative annual energy efficiency MWh savings goals through 2040, adds expanded electrification measures to those goals, increases low-income commitments and adds a new performance adjustment to the energy efficiency formula rate. ComEd expects its annual spend to increase in 2023 through 2040 to achieve these energy efficiency MWh savings goals, which will be deferred as a separate regulatory asset that will be recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures.

Energy Efficiency Formula Rate. FEJA allows ComEd to defer energy efficiency costs (except for any voltage optimization costs which are recovered through the electric distribution formula rate) as a separate regulatory asset that is recovered through the energy efficiency formula rate over the weighted average useful life, as approved by the ICC, of the related energy efficiency measures. ComEd earns a return on the energy efficiency regulatory asset at a rate equal to its weighted average cost of capital, which is based on a year-end capital structure and calculated using the same methodology applicable to ComEd’s electric distribution formula rate. Beginning January 1, 2018, the ROE that ComEd earns on its energy efficiency regulatory asset is subject to a maximum downward or upward adjustment of 200 basis points if ComEd’s cumulative persisting annual MWh savings falls short of or exceeds specified percentage benchmarks of its annual incremental savings goal. ComEd is required to file an update to its energy efficiency formula rate on or before June 1st each year, with resulting rates effective in January of the following year. The annual update is based on projected current year energy efficiency costs, PJM capacity revenues, and the projected year-end regulatory asset balance less any related deferred income taxes (initial year revenue requirement). The update also reconciles any differences between the revenue requirement in effect for the prior year and actual costs incurred from the year (annual reconciliation). The approved energy efficiency formula rate also provides for revenue decoupling provisions similar to those in ComEd’s electric distribution formula rate.

During 2023, the ICC approved the following total increases in ComEd's requested energy efficiency revenue requirement:


Filing Date	Requested Revenue Requirement Increase		Approved Revenue Requirement Increase(a)		Approved ROE		Approval Date	Rate Effective Date
May 26, 2023	$	118	$	118	8.91	%	November 30, 2023	January 1, 2024

_________

(a)ComEd's 2024 approved revenue requirement above reflects an increase of $71 million for the initial year revenue requirement for 2024 and a increase of $47 million related to the annual reconciliation for 2022. The revenue requirement for 2024 provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 6.48% inclusive of an allowed ROE of 8.91%, reflecting the monthly average yields for 30-year treasury bonds plus 580 basis points. The revenue requirement for the 2022 reconciliation year provides for a weighted average debt and equity return on the energy efficiency regulatory asset and rate base of 7.47% inclusive of an allowed ROE of 10.89%, which includes an upward performance adjustment that increased the ROE. The performance adjustment can either increase or decrease the ROE based upon the achievement of energy efficiency savings goals. See table below for ComEd's regulatory assets associated with its energy efficiency formula rate.

Other Federal Regulatory Matters

FERC Audit. ComEd is subject to periodic audits and investigations by FERC. FERC’s Division of Audits and Accounting initiated a nonpublic audit of ComEd in April 2021 evaluating ComEd’s compliance with (1) approved terms, rates and conditions of its federally regulated service; (2) accounting requirements of the Uniform System of Accounts; (3) reporting requirements of the FERC Form 1; and (4) the requirements for record retention. The audit period extends back to January 1,

2017. During the first quarter of 2023, ComEd was provided with information from FERC about several potential findings, including ComEd's methodology regarding the allocation of certain overhead costs to capital under FERC regulations. Based on the preliminary findings and discussions with FERC staff, ComEd determined that a loss was probable and recorded a regulatory liability to reflect its best estimate of that loss in the first quarter of 2023.

On July 27, 2023, FERC issued a final audit report which included, among other things, findings and recommendations related to ComEd's methodology regarding the allocation of certain overhead costs to capitalized construction costs under FERC regulations, including a suggestion that refunds may be due to customers for amounts collected in previous years. On August 28, 2023, ComEd filed a formal notice of the issues it will contest. On December 14, 2023, FERC appointed a settlement judge for the contested overhead allocation findings and set the matter for a trial-type hearing. That hearing process has been held in abeyance while a formal settlement process, which began in February 2024, takes place. The final outcome and resolution of any contested audit issues as well as a reasonable estimate of potential future losses cannot be accurately estimated at this stage; however, the final resolution of these matters could result in recognition of future losses, above the amounts currently accrued, that could be material to the Exelon and ComEd financial statements.

Regulatory Assets and Liabilities

Regulatory assets represent incurred costs that have been deferred because of their probable future recovery from customers through regulated rates. Regulatory liabilities represent the excess recovery of costs or accrued credits that have been deferred because it is probable such amounts will be returned to customers through future regulated rates or represent billings in advance of expenditures for approved regulatory programs.

The following tables provide information about the regulatory assets and liabilities of ComEd as of December 31, 2023 and 2022.


Regulatory Assets (Account 182.3):	December 31, 2023		December 31, 2022
AMI programs - legacy meters	$	28	$	48
Asset retirement obligations	104		99
Carbon mitigation credit	673		843
COVID-19	11		20
Deferred income taxes	284		—
Electric distribution formula rate annual reconciliations	787		271
Electric distribution formula rate significant one-time events	89		115
Energy efficiency costs	1,691		1,434
MGP remediation costs	286		293
Renewable energy	134		85
Uncollectible accounts expense	78		47
Zero emissions program	58		—
Other	174		169
Total Regulatory Assets	$	4,397	$	3,424

Regulatory Liabilities (Account 254):	December 31, 2023		December 31, 2022
Decommissioning the Regulatory Agreement Units	$	2,954	$	2,660
Deferred income taxes	2,178		2,005
Electric energy costs	5		13

Renewable portfolio standards costs	1,102		810
Transmission formula rate annual reconciliations	14		3
Other	1		8
Total Regulatory Liabilities	$	6,254	$	5,499

Descriptions of the regulatory assets and liabilities included in the tables above are summarized below, including their recovery and amortization periods.


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
AMI programs - Legacy Meters	Represents early retirement costs of legacy meters.	2028	Yes


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
Asset retirement obligations	Represents future legally required removal costs associated with existing AROs.	Over the life of the related assets.	Yes, once the removal activities have been performed.
Carbon mitigation credit	Represents CMC procurement costs and credits as well as reasonable costs ComEd has incurred to implement and comply with the CMC procurement process.	2024	No
COVID-19	Represents incremental credit losses and direct costs related to COVID-19 incurred primarily in 2020. Direct costs consistent primarily of costs to acquire personal protective equipment, costs for cleaning supplies and services, and costs to hire healthcare professionals to monitor the health of employees.	2025	Yes
Decommissioning the Regulatory Agreement Units	Represents estimated excess funds at the end of decommissioning the Regulatory Agreement Units. See below regarding Decommissioning the Regulatory Agreement Units for additional information.	Not currently being refunded.	No
Dedicated facilities charge	Represents the timing difference between the recovery of certain transmission-related assets and their depreciable life.	Depreciable life of the related assets.	Yes


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
Deferred income taxes	Represents deferred income taxes that are recoverable or refundable through customer rates, primarily associated with accelerated depreciation, the equity component of AFUDC, and the effects of income tax rate changes, including those resulting from the TCJA.	Amounts are recoverable over the period in which the related deferred income taxes reverse, which is generally based on the expected life of the underlying assets. For TCJA, generally refunded over the remaining depreciable life of the underlying assets, except in certain jurisdictions where the commissions have approved a shorter refund period for certain assets not subject to IRS normalization rules.	No
Electric distribution formula rate annual reconciliations	Represents under/(over)-recoveries related to electric distribution service costs recoverable through ComEd's performance-based formula rate, which is updated annually with rates effective on January 1st.	2025	Yes
Electric distribution formula rate significant one-time events	Represents deferred distribution service costs related to ComEd's significant one-time events (e.g., storm costs), which are recovered over 5 years from date of the event.	2027	Yes
Electric energy costs	Under (over) recoveries related to energy related costs recoverable (refundable) under approved rate riders.	2025	No
Energy efficiency costs	Represents ComEd's costs recovered through the energy efficiency formula rate tariff and the reconciliation of the difference of the revenue requirement in effect for the prior year and the revenue requirement based on actual prior year costs. Deferred energy efficiency costs are recovered over the weighted average useful life of the related energy measure.	2035	Yes
MGP remediation costs	Represents environmental remediation costs for MGP sites.	Over the expected remediation period. See Note 12 - Commitments and Contingencies for additional information.	No
Removal costs	Represents amounts received from customers through depreciation rates to cover the future non–legally required cost to remove property, plant and equipment, which reduces rate base for ratemaking purposes.	Liability is reduced as costs are incurred.	Yes
Renewable energy	Represents the change in fair value of ComEd‘s 20-year floating-to-fixed long-term renewable energy swap contracts.	2032	No


Line Item	Description	End Date of Remaining Recovery/Refund Period	Return
Renewable portfolio standard costs	Represents an overcollection of funds from both ComEd customers and alternative retail electricity suppliers to be spent on future renewable energy commitments.	$1,033 million to be determined in pending ICC annual reconciliation for the Renewable Energy Adjustment rider. $69 million to be determined based on the Long-Term Renewable Resources Procurement Plan developed by the Illinois Power Agency	No
Transmission formula rate annual reconciliations	Under (over)-recoveries related to transmission service costs recoverable through ComEd’s FERC formula rates, which are updated annually with rates effective each June 1st.	2025	Yes
Under-recovered uncollectible accounts expense	Amounts represent the difference between annual uncollectible accounts loss expense and revenues collected in rates through ICC-approved riders. The difference between uncollectible accounts expense and revenues collected through rider each calendar year is recovered over a twelve-month period beginning in June of the following calendar year.	2024	No
Zero emission credit	Represents ZEC procurement costs and any reasonable costs ComEd has incurred to implement and comply with the ZEC procurement process.	Over 9 months starting with the September billing period and ending with the following May billing period.	No

Decommissioning the Regulatory Agreement Units

The regulatory agreements with the ICC dictates obligations related to the shortfall or excess of Nuclear Decommissioning Trust (NDT) funds necessary for decommissioning the former ComEd units on a unit-by-unit basis. Given no further recovery from customers is permitted and Constellation retains an obligation to ultimately return excess funds to ComEd customers (on a unit-by-unit basis), to the extent excess funds are expected for each unit, decommissioning-related activities prior to separation on February 1, 2022 were offset in the Statement of Income with an offsetting adjustment to regulatory liabilities and noncurrent receivable from Generation (which is reported within Miscellaneous deferred debits on the Balance Sheet). Following the separation, decommissioning-related activities result in an adjustment to other deferred debits and an equal adjustment to the regulatory liabilities at ComEd. However, given the asymmetric settlement provision that does not allow for continued recovery from ComEd customers in the event of a shortfall, recognition of a regulatory asset is not permissible.

Capitalized Ratemaking Amounts Not Recognized

As of December 31, 2023 and 2022, ComEd had $32 million and $8 million, respectively, of authorized amounts capitalized for ratemaking purposes related to earnings on shareholders' investment on its electric distribution formula rate regulatory assets that are not recognized for financial reporting purposes on the Balance Sheet. These amounts will be recognized as revenues in the Statement of Income in the periods they are billable to customers.

3. Accounts Receivable

Accumulated Provision for Uncollectible Accounts

The following table presents the rollforward of Accumulated Provision for Uncollectible Accounts on Customer Accounts Receivable (Account 144).


	Year Ended December 31, 2023
Balance as of December 31, 2022	$	59
Plus: Current period provision for uncollectible accounts(a)	53
Less: Write-offs, net of recoveries(b)	43
Balance as of December 31, 2023	$	69


	Year Ended December 31, 2022
Balance as of December 31, 2021	$	73
Plus: Current period provision for uncollectible accounts	29
Less: Write-offs, net of recoveries	43
Balance as of December 31, 2022	$	59

__________

(a)The change in the current period provision for expected credit losses is primarily a result of increased receivable balances.

(b)Recoveries were not material to ComEd.

The following table presents the rollforward of Accumulated Provision for Uncollectible Accounts on Other Accounts Receivable (Account 144).


	Year Ended December 31, 2023
Balance as of December 31, 2022	$	17
Plus: Current period provision for uncollectible accounts	5
Less: Write-offs, net of recoveries(a)	5
Balance as of December 31, 2023	$	17


	Year Ended December 31, 2022
Balance as of December 31, 2021	$	17
Plus: Current period benefit for uncollectible accounts	3
Less: Write-offs, net of recoveries	3
Balance as of December 31, 2022	$	17

__________

(a) Recoveries were not material to ComEd.

Accrued Utility Revenues

ComEd accrued $351 million and $223 million of unbilled revenues as of December 31, 2023 and December 31, 2022, respectively, in Account 173, Accrued Utility Revenues.

Purchase of Customer and Other Accounts Receivable

ComEd is required under legislation and regulations in Illinois to purchase certain receivables from alternative retail electric suppliers that participate in its consolidated billing. The following table presents the total receivable ComEd purchased:


	Year Ended December 31,
	2023		2022
Total receivables purchased	$	942	$	965

4. Property, Plant, and Equipment

The following table presents the average service life for each asset category in number of years as of December 31, 2023:


Asset Category						Average Service Life (years)
Electric - transmission and distribution						3-80
Other property, plant and equipment						30-50

The following table presents the annual depreciation rates for each asset category:

Annual Depreciation Rates

December 31, 2023

December 31, 2022

Electric-transmission and distribution

3.04%

3.02%

Allowance for Funds Used During Construction (AFUDC)

The credits to AFUDC debt and equity were $72 million and $54 million for the years ended December 31, 2023 and 2022, respectively.

See Note 1 - Significant Accounting Policies for additional information regarding property, plant and equipment policies. See Note 10 - Debt and Credit Agreements for additional information regarding ComEd's property, plant and equipment subject to mortgage liens.

5. Asset Retirement Obligations

ComEd has AROs primarily associated with the abatement and disposal of equipment and buildings contaminated with asbestos and polychlorinated biphenyls (PCBs). See Note 1 — Significant Accounting Policies for additional information on ComEd’s accounting policy for AROs

The following table provides a rollforward of the non-nuclear AROs reflected on ComEd’s Balance Sheet from December 31, 2021 to December 31, 2023:


AROs at December 31, 2021 (Account 230)	$	146
Net increase due to changes in, and timing of, estimated future cash flows	2
Accretion expense(a)	4
Payments	(2)
AROs at December 31, 2022 (Account 230)	$	150
Net increase due to changes in, and timing of, estimated future cash flows	(3)
Accretion expense(a)	6
Payments	(2)
AROs at December 31, 2023 (Account 230)	$	151

__________

(a)The majority of the accretion is recorded as an increase to a regulatory asset (Account 182.3, Other Regulatory Assets) due to the associated regulatory treatment.

6. Intangible Assets

ComEd’s gross amount of goodwill, accumulated impairment losses and carrying amount of goodwill were $4,608 million, $1,983 million and $2,625 million, respectively, for both December 31, 2023 and 2022. The gross amount reflects goodwill recorded in 2000 from the PECO/Unicom (predecessor parent company of ComEd) merger net of amortization, resolution of tax matters and other non-impairment related changes as allowed under previous authoritative guidance.

Goodwill is recorded in Account 114, Electric Plant Acquisition Adjustments and Account 115, Accumulated Provision for Amortization of Electric Plant Acquisition Adjustments, as approved by FERC (Docket No. AC01-38-000). Goodwill is not amortized, but is subject to an assessment for impairment at least annually, or more frequently if events occur or circumstances change that would more likely than not reduce the fair value of the ComEd reporting unit below its carrying amount. A reporting unit is an operating segment or one level below an operating segment (known as a component) and is the

level at which goodwill is assessed for impairment. A component of an operating segment is a reporting unit if the component constitutes a business for which discrete financial information is available and its operating results are regularly reviewed by segment management. ComEd has a single operating segment. There is no level below this operating segment for which operating results are regularly reviewed by segment management. Therefore, ComEd’s operating segment is considered its only reporting unit.

Entities assessing goodwill for impairment have the option of first performing a qualitative assessment to determine whether a quantitative assessment is necessary. As part of the qualitative assessments, ComEd evaluates, among other things, management's best estimate of projected operating and capital cash flows for their businesses, outcomes of recent regulatory proceedings, changes in certain market conditions, including the discount rate and regulated utility peer EBITDA multiples, and the passing margin from its last quantitative assessments performed. If an entity bypasses the qualitative assessment, a quantitative, fair value-based assessment is performed, which compares the fair value of the reporting unit to its carrying amount, including goodwill. If the carrying amount of the reporting unit exceeds its fair value, the entity recognizes an impairment charge, which is limited to the amount of goodwill.

Application of the goodwill impairment assessment requires management judgment, including the identification of reporting units and determining the fair value of the reporting unit, which management estimates using a weighted combination of a discounted cash flow analysis and a market multiples analysis. Significant assumptions used in these fair value analyses include discount and growth rates, utility sector market performance and transactions, projected operating and capital cash flows for ComEd's business and the fair value of debt.

2023 and 2022 Goodwill Impairment Assessment. ComEd qualitatively determined that it was more likely than not that the fair value of its reporting unit exceeded the carrying value and, therefore, did not perform quantitative assessments as of November 1, 2023 and 2022. On December 14, 2023, due to the issuance of the ICC's final order rejecting ComEd’s proposed Grid Plan and establishing retail rates for 2024-2027 as further discussed in Note 2 - Regulatory Matters, Exelon’s stock price decreased approximately 10% triggering an interim quantitative assessment for potential goodwill impairment at ComEd. ComEd performed a quantitative assessment as of December 31, 2023, comparing the estimated fair value of ComEd to its carrying value, and determined there was no indication of goodwill impairment

While the annual assessments indicated no impairments, certain assumptions used to estimate reporting unit fair values are highly sensitive to changes. Adverse regulatory actions or changes in significant assumptions could potentially result in future impairments of ComEd's goodwill, which could be material.

7. Income Taxes

Components of Income Tax Expense or Benefit

Income tax expense (benefit) from continuing operations is comprised of the following components:


	For the Year Ended December 31,
	2023		2022
Included in operations:
Federal
Current	$	136	$	28
Deferred	39		118
Investment tax credit amortization	(1)		(1)
State
Current	(10)		(6)
Deferred	150		124
Total (Accounts 409.1, 409.2, 410.1, 411.1, 411.4)	$	314	$	263

The effective income tax rate from continuing operations varies from the U.S. Federal statutory rate principally due to the following:


	For the Year Ended December 31,
	2023		2022
U.S. Federal statutory rate	21.0	%	21.0	%
Increase (decrease) due to:
State income taxes, net of Federal income tax benefit	7.8		7.9

Amortization of investment tax credit, including deferred taxes on basis difference	(0.1)		(0.1)
Plant basis differences	(0.4)		(0.6)
Production tax credits and other credits	(0.4)		(0.3)
Excess deferred tax amortization	(5.4)		(5.6)

Other	(0.2)		—
Effective income tax rate	22.3	%	22.3	%

The tax effects of temporary differences, which give rise to significant portions of the deferred tax assets and liabilities, as of December 31, 2023 and 2022 are presented below:


	2023		2022
Deferred tax liabilities, net:
Plant basis differences	$	(4,983)	$	(4,821)
Derivative financial instruments	37		23


Deferred pension and post-retirement obligation	(299)		(300)
Deferred debt refinancing costs	(5)		(5)
Regulatory	(405)		(131)
Corporate alternative minimum tax	118		—
Other, net	226		222
Deferred income tax liabilities, net (Accounts 190, 282 and 283)	$	(5,311)	$	(5,012)
Unamortized investment tax credits (Account 255)	(7)		(8)

Total deferred income tax liabilities, net and unamortized investment tax credits	$	(5,318)	$	(5,020)

The following table provides ComEd's carryforwards as of December 31, 2023:


	As of December 31, 2023
Federal
Minimum tax credit carryforward(a)	$	118

__________

(a)The Corporate Alternative Minimum Tax credit carryfoward has an indefinite carryforward period.

Tabular reconciliation of unrecognized tax benefits

The following table provides a GAAP reconciliation of ComEd’s unrecognized tax benefits as of December 31, 2023 and 2022:


Unrecognized tax benefits at January 1, 2022	$	15
Changes to positions that only affect timing	(1)
Increases based on tax positions related to 2022	1
Increases based on tax positions prior to 2022	1
Unrecognized tax benefits at December 31, 2022	$	16

Unrecognized tax benefits at January 1, 2023	$	16
Changes to positions that only affect timing	(1)
Increases based on tax positions related to 2023	1
Increases based on tax positions prior to 2023	(8)
Unrecognized tax benefits at December 31, 2023	$	8

Recognition of unrecognized tax benefits

As of December 31, 2023 and December 31, 2022, ComEd has $6 million and $5 million, respectively, of unrecognized tax benefits that, if recognized, would decrease the effective tax rate.

Reasonably possible the total amount of unrecognized tax benefits could significantly increase or decrease within 12 months after the reporting date

As of December 31, 2023, ComEd has no unrecognized tax benefits that could significantly decrease within the 12 months after the reporting date.

Total amounts of interest and penalties recognized

As of December 31, 2023 and December 31, 2022, ComEd has accrued interest of $1 million and $1 million, respectively, and no penalties related to income tax positions.

Description of tax years that remain subject to examination by major jurisdiction


			Open Years
Federal consolidated income tax returns			2010-2022
Illinois unitary corporate income tax returns			2012-2022

Other Tax Matters

Corporate Alternative Minimum Tax

On August 16, 2022, the IRA was signed into law and implemented a new corporate alternative minimum tax (CAMT) that imposes a 15% tax on modified GAAP net income. Corporations are entitled to a tax credit (minimum tax credit) to the extent the CAMT liability exceeds the regular tax liability. This amount can be carried forward indefinitely and used in future years when regular tax exceeds the CAMT.

Based on the existing statue, ComEd will be subject to and will report the CAMT on a separate Registrant basis in the Consolidated Statements of Operations and Comprehensive Income and the Consolidated Balance Sheets. The deferred tax asset related to the minimum tax credit carryforward will be realized to the extent ComEd’s consolidated deferred tax liabilities exceed the minimum tax credit carryforward. ComEd’s deferred tax liabilities are expected to exceed the minimum tax credit carryforward for the foreseeable future and thus no valuation allowance is required. ComEd is continuing to assess the financial statement impacts of the IRA and will update estimates based on future guidance issued by the U.S. Treasury.

Long-Term Marginal State Income Tax Rate

Quarterly, Exelon reviews and updates its marginal state income tax rates for changes in state apportionment. ComEd remeasures its existing deferred income tax balances to reflect the changes in marginal rates, which results in either an increase or decrease to their net deferred income tax liability balances. ComEd records corresponding regulatory liabilities or assets to the extent such amounts are probable of settlement or recovery through customer rates and an adjustment to income tax expense for all other amounts. There were no adjustments to ComEd's deferred income tax liability balance for the years ended December 31, 2023 and 2022.

Allocation of Tax Benefits

ComEd is party to an agreement with Exelon and other subsidiaries of Exelon that provides for the allocation of consolidated tax liabilities and benefits (Tax Sharing Agreement). The Tax Sharing Agreement provides that each party is allocated an amount of tax similar to that which would be owed had the party been separately subject to tax. In addition, any net federal and state benefits attributable to Exelon is reallocated to ComEd and the other Registrants. That allocation is treated as a contribution to the capital of the party receiving the benefit.

ComEd recorded a federal tax benefit allocation from Exelon under the Tax Sharing Agreement as of December 31, 2023 of $12 million. ComEd did not record a federal tax benefit allocation from Exelon under the Tax Sharing Agreement as of December 31, 2022.

8. Retirement Benefits

Defined Benefit Pension and Other Postretirement Employee Benefits

Effective, February 1, 2022, in connection with the separation, pension and other postretirement employee benefits (OPEB) obligations and assets for current and former employees of the Constellation business and certain other former employees of Exelon and its subsidiaries transferred to pension and OPEB plans and trusts maintained by Constellation or its subsidiaries.

As a result of the separation, Exelon restructured certain of its qualified pension plans. Pension obligations and assets for current and former employees continuing with Exelon and who were participants in the Exelon Employee Pension Plan for Clinton, TMI, and Oyster Creek, and Pension Plan of Constellation Energy Nuclear Group, LLC, were merged into the Pension Plan of Constellation Energy Group, Inc., which was subsequently renamed, Exelon Pension Plan (EPP). Exelon employees who participated in these plans prior to the separation now participate in the EPP. The merging of the plans did not change the benefits offered to the plan participants and, this, had no impact on Exelon's pension obligations.

The listing below shows the pension and OPEB plans in which ComEd employees participated as of December 31, 2023:

Name of Plan(a):

Qualified Pension Plans:

•Exelon Corporation Retirement Program

•Exelon Corporation Pension Plan for Bargaining Unit Employees

Non-Qualified Pension Plans:

•Exelon Corporation Supplemental Pension Benefit Plan and 2000 Excess Benefit Plan

•Exelon Corporation Supplemental Management Retirement Plan

OPEB Plans:

•Exelon Corporation Health Care Program

•Exelon Corporation Employees' Life Insurance Plan

•Exelon Corporation Health Reimbursement Arrangement Plan

__________

(a)Employees generally remain in their legacy benefit plans when transferring between operating companies.

Cost Allocation to ComEd

ComEd accounts for its participation in Exelon’s pension and OPEB plans by applying multi-employer accounting. Components of pension and OPEB costs and contributions have been, and will continue to be, allocated to ComEd based on both active and retired employee participation in each plan.

The amounts below represent ComEd's allocated portion of the pension and OPEB plan costs which were included in Operating expenses (Account 401) within ComEd's Statement of Income and Utility Plant (Account 101-106, 114) within ComEd's Balance Sheet for the years ended December 31, 2023 and 2022:


	2023		2022
Pension and OPEB	$	26	$	60

Contributions

The following table provides ComEd's contribution to the pension and OPEB plans for the years ended December 31, 2023 and 2022:


	2023		2022
Pension	$	24	$	176
OPEB	17		8

Management considers various factors when making pension funding decisions, including actuarially determined minimum contribution requirements under ERISA, contributions required to avoid benefit restrictions and at-risk status as defined by the Pension Protection Act of 2006 (the Act), management of the pension obligation and regulatory implications. The Act requires the attainment of certain funding levels to avoid benefit restrictions (such as an inability to pay lump sums or to accrue benefits prospectively), and at-risk status (which triggers higher minimum contribution requirements and participant notification). The projected contributions below reflect a funding strategy to make annual contributions with the objective of achieving 100% funded status on an accumulated benefit obligation (ABO) basis over time. This level funding strategy helps minimize volatility of future period required pension contributions. Unlike the qualified pension plans, Exelon’s non-qualified pension plans are not funded, given that they are not subject to statutory minimum contribution requirements.

While OPEB plans are also not subject to statutory minimum contribution requirements, Exelon does fund certain of its plans. For Exelon's funded OPEB plans, contributions generally equal accounting costs, however, Exelon’s management has historically considered several factors in determining the level of contributions to its OPEB plans, including liabilities management, levels of benefit claims paid, and regulatory implications (amounts deemed prudent to meet regulatory expectations and best assure continued rate recovery). The amounts below include benefit payments related to unfunded plans.

The following table provides ComEd's planned contributions to the qualified pension plans, planned benefit payments to non-qualified pension plans, and planned contributions to OPEB plans in 2024.


	Qualified Pension Plans		Non-Qualified Pension Plans		OPEB
Planned contributions	$	3	$	1	$	18

Defined Contribution Savings Plan

ComEd participates in various 401(k) defined contribution savings plans that are sponsored by Exelon. The plans are qualified under applicable sections of the IRC and allow employees to contribute a portion of their pre-tax and/or after-tax income in accordance with specified guidelines. ComEd matches a percentage of the employee contributions up to certain limits. The following table presents the employer contributions and employer matching contributions to the savings plans during the years ended December 31, 2023 and 2022:


	2023		2022
Savings plan matching contributions	$	47	$	39

9. Derivative Financial Instruments

ComEd uses derivative instruments to manage commodity price risk related to ongoing business operations. ComEd does not execute derivatives for speculative or proprietary trading purposes.

Authoritative guidance requires that derivative instruments be recognized as either assets or liabilities at fair value, with changes in fair value of the derivative recognized in earnings immediately. Other accounting treatments are available through special election and designation, provided they meet specific, restrictive criteria both at the time of designation and on an ongoing basis. These alternative permissible accounting treatments include Normal Purchase Normal Sale (NPNS), cash flow hedges and fair value hedges. All derivative economic hedges related to commodities, referred to as economic hedges, are recorded at fair value through earnings and offset by a corresponding regulatory asset or liability. For all NPNS derivative instruments, accounts receivable or accounts payable are recorded when derivatives settle and revenue or expense is recognized in earnings as the underlying physical commodity is sold or consumed.

ComEd’s use of cash collateral is generally unrestricted unless ComEd is downgraded below investment grade.

Commodity Price Risk

ComEd employs established policies and procedures to manage its risk associated with market fluctuations in commodity prices by entering into physical and financial derivative contracts, which are either determined to be non-derivative or classified as economic hedges.

ComEd procures electric supply through a competitive procurement process approved by the ICC. ComEd’s hedging programs are intended to reduce exposure to energy price volatility and have no direct earnings impact as the costs are fully recovered from customers through regulatory-approved recovery mechanisms. The following table provides a summary of ComEd's primary derivative hedging instruments, listed by commodity and accounting treatment.


Commodity	Accounting Treatment	Hedging Instrument
Electricity	NPNS	Fixed price contracts based on all requirements in the IPA procurement plans.
Electricity	Changes in fair value of economic hedge recorded to an offsetting regulatory asset or liability(a)	20-year floating-to-fixed energy swap contracts beginning June 2012 based on the renewable energy resource procurement requirements in the Illinois Settlement Legislation of approximately 1.3 million MWhs per year.

__________

(a)See Note 2 - Regulatory Matters for additional information

The following table provides a summary of the derivative fair value balances recorded by ComEd as of December 31, 2023 and 2022:


	December 31, 2023		December 31, 2022
Mark-to-market derivative liabilities - current (Account 242)	$	(27)	$	(5)
Mark-to-market derivative liabilities - noncurrent (Account 253)	(106)		(79)
Total mark-to-market derivative liabilities	$	(133)	$	(84)

Credit Risk

ComEd would be exposed to credit-related losses in the event of non-performance by counterparties on executed derivative instruments. The credit exposure of derivative contracts, before collateral, is represented by the fair value of contracts at the reporting date.

ComEd has contracts to procure electric supply that provide suppliers with a certain amount of unsecured credit. If the exposure on the supply contract exceeds the amount of unsecured credit, the suppliers may be required to post collateral. The net credit exposure is mitigated primarily by the ability to recover procurement costs through customer rates. As of December 31, 2023 and 2022, the amount of cash collateral held with external counterparties were $146 million and $77 million, respectively, which is recorded in Miscellaneous Current and Accrued Liabilities in the Balance Sheet (Account 242).

ComEd's electric supply procurement contracts do not contain provisions that would require them to post collateral.

10. Debt and Credit Agreements

Short-Term Borrowings

ComEd meets its short-term liquidity requirements primarily through the issuance of commercial paper. ComEd may use its credit facilities for general corporate purposes, including meeting short-term funding requirements and the issuance of letters of credit.

Commercial Paper

The following table reflects ComEd's commercial paper programs supported by the revolving credit agreements as of December 31, 2023 and 2022:


Credit Facility Size as of December 31,				Outstanding Commercial Paper as of December 31,				Average Interest Rate on Commercial Paper Borrowings for the Year Ended December 31,
2023(a)		2022(a)		2023		2022		2023		2022
$	1,000	$	1,000	$	202	$	427	5.53	%	4.71	%

__________

(a)Excludes credit facility agreements arranged at minority and community banks. See below for additional information.

In order to maintain its commercial paper program in the amounts indicated above, ComEd must have credit facilities in place, at least equal to the amount of its commercial paper program. ComEd does not issue commercial paper in an aggregate amount exceeding the then available capacity under its credit facility.

As of December 31, 2023, ComEd had the following aggregate bank commitments, credit facility borrowings, and available capacity under its credit facility:


							Available Capacity as of December 31, 2023
Facility Type	Aggregate Bank Commitment		Facility Draws		Outstanding Letters of Credit		Actual		To Support Additional Commercial Paper
Syndicated Revolver	$	1,000	$	—	$	10	$	990	$	778

The following table reflects ComEd's credit facility agreements arranged at minority and community banks as of December 31, 2023 and 2022. These are excluded from the Maximum Program Size and Aggregate Bank Commitment amounts within the two tables above and the facilities are solely used to issue letters of credit.


Aggregate Bank Commitments(a)		Outstanding Letters of Credit
2023	2022	2023	2022
40	40	7	7

__________

(a)These facilities were entered into on October 6, 2023 and expire October, 4, 2024.

Short-Term Loan Agreements

On October 4, 2022, ComEd entered into a 364-day term loan agreement for $150 million with a variable rate equal to Secured Overnight Financing Rate (SOFR) plus 0.75% and an expiration date of October 3, 2023. The proceeds from this loan were used to repay outstanding commercial paper obligations. The loan agreement is reflected in ComEd's Balance Sheet within Notes Payable (Account 231). The balance of the loan was repaid on January 13, 2023 in conjunction with the $400 million and $575 million First Mortgage Bond agreements that were entered into on January 3, 2023.

On May 9, 2023, ComEd entered into a 364-day term loan for $400 million with a variable rate equal to SOFR plus 1.00% and an expiration date of May 7, 2024. The proceeds from this loan were used to repay outstanding commercial paper obligations and for general corporate purposes. The loan agreement is reflected in ComEd's Balance Sheets within Notes Payable (Account 231).

Revolving Credit Agreements

On February 1, 2022, ComEd entered into a new 5-year revolving credit facility that replaced its existing syndicated revolving credit facility. The credit agreement has an aggregate bank commitment of $1 billion and an interest rate of SOFR plus 1.00%.

Borrowings under ComEd’s revolving credit agreements bear interest at a rate based upon either the prime rate or a SOFR-based rate, plus an adder based upon ComEd’s credit rating. ComEd has an adder of 0 basis points for prime based borrowings and 100 basis points for SOFR-based borrowings. If ComEd loses its investment grade rating, the maximum adders for prime rate borrowings and SOFR-based rate borrowings would be 65 basis points and 165 basis points, respectively. The credit agreements also require ComEd to pay a facility fee based upon the aggregate commitments. The fee varies depending upon the credit rating of ComEd. ComEd had no outstanding amounts on the revolving credit facilities as of December 31, 2023.

Long-Term Debt

The following tables present the outstanding long-term debt at ComEd as of December 31, 2023 and 2022:


			December 31,
	Rates	Maturity Date	2023		2022
Long-term debt
First Mortgage Bonds:
Fixed rates (Account 221)(a)	2.20 - 6.45%	2024 - 2053	$	11,603	$	10,629
Notes payable and other (Accounts 224, 227)	7.49%	2053	8		8
Total long-term debt			$	11,611	$	10,637
Unamortized debt discount and premium, net (Account 225 and 226)			(28)		(27)
Long-term debt			$	11,583	$	10,610

Long-term debt to financing trusts(b)
Subordinated debentures to ComEd Financing III (Account 223)	6.35%	2033	$	206	$	206

__________

(a)Substantially all of ComEd’s assets other than expressly excepted property are subject to the lien of its mortgage indenture.

(b)Amount owed to this financing trust is recorded as Long-term debt to financing trust within ComEd's Balance Sheet.

The following table presents the long-term debt that was issued on January 10, 2023:

Type

Interest
Rate

Maturity

Amount

Use of Proceeds

First Mortgage Bonds Series 134

4.90

February 1, 2023

400

Repay outstanding commercial paper obligations, to repay a $150 million term load with U.S. Bank National Association and to fund other general corporate purposes

First Mortgage Bonds Series 135

5.30

February 1, 2053

575

Repay outstanding commercial paper obligations, to repay a $150 million term loan with U.S. Bank National Association and to fund other general corporate purposes

Long-term debt maturities at ComEd in the periods 2024 through 2028 and thereafter are as follows:


Year
2024	$	250
2025	—
2026	500
2027	350
2028	550
Thereafter	10,167		(a)
Total	$	11,817

________

(a)Includes $206 million due to ComEd financing trust.

Debt Covenants

As of December 31, 2023, the ComEd is in compliance with debt covenants.

11. Fair Value of Financial Assets and Liabilities

ComEd measures and classifies fair value measurements in accordance with the hierarchy as defined by authoritative guidance. The hierarchy prioritizes the inputs to valuation techniques used to measure fair value into three levels as follows:

•Level 1 — quoted prices (unadjusted) in active markets for identical assets or liabilities that ComEd has the ability to liquidate as of the reporting date.

•Level 2 — inputs other than quoted prices included within Level 1 that are directly observable for the asset or liability or indirectly observable through corroboration with observable market data.

•Level 3 — unobservable inputs, such as internally developed pricing models or third-party valuations for the asset or liability due to little or no market activity for the asset or liability.

Fair Value of Financial Liabilities Recorded at Amortized Cost

The following tables present the carrying amounts and fair values of ComEd's short-term liabilities, long-term debt, and trust preferred securities (long-term debt to financing trusts) as of December 31, 2023 and 2022. ComEd has no financial liabilities classified as Level 1 or measured using the NAV practical expedient.

The carrying amounts of ComEd's short-term liabilities as presented on ComEd's Balance Sheet are representative of their fair value (Level 2) because of the short-term nature of these instruments.


	December 31, 2023										December 31, 2022
	Carrying Amount		Fair Value								Carrying Amount		Fair Value
			Level 1		Level 2		Level 3		Total				Level 1		Level 2		Level 3		Total

Long-term debt (Accounts 221, 224-227)(a)	$	11,583	$	—	$	10,210	$	—	$	10,210	$	10,610	$	—	$	9,006	$	—	$	9,006
Long-term debt to financing trust (Account 223)	206		—		—		208		208		206		—		—		204		204

(a) Includes unamortized debt discount and premium, net, and purchase accounting fair value adjustments which are not fair valued. Refer to Note 10 - Debt and Credit Agreements.

ComEd uses the following methods and assumptions to estimate fair value of financial liabilities recorded at carrying cost:


Type	Level	Valuation
Long-Term Debt, including amounts due within one year
Taxable Debt Securities	2	The fair value is determined by a valuation model that is based on a conventional discounted cash flow methodology and utilizes assumptions of current market pricing curves. ComEd obtains credit spreads based on trades of existing ComEd debt securities as well as other issuers in the utility sector with similar credit ratings. The yields are then converted into discount rates of various tenors that are used for discounting the respective cash flows of the same tenor for each bond or note.
Long-Term Debt to Financing Trusts
Long-Term Debt to Financing Trusts	3	Fair value is based on publicly traded securities issued by the financing trusts. Due to low trading volume of these securities and qualitative factors, such as market conditions, investor demand, and circumstances related to each issue, this debt is classified as Level 3..

Recurring Fair Value Measurements

The following table presents assets and liabilities measured and recorded at fair value on ComEd’s Balance Sheets on a recurring basis and their level within the fair value hierarchy as of December 31, 2023 and 2022. ComEd has no financial assets or liabilities measured using the NAV practical expedient:


December 31, 2023	Level 1		Level 2		Level 3		Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)	$	453	$	—	$	—	$	453

Total assets	453		—		—		453
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)	—		(8)		—		(8)
Commodity derivative liabilities(b) (Accounts 242, 253)	—		—		(133)		(133)
Total liabilities	—		(8)		(133)		(141)
Total net assets (liabilities)	$	453	$	(8)	$	(133)	$	312

December 31, 2022	Level 1		Level 2		Level 3		Total
Assets
Cash equivalents (Accounts 132-134, 136, and 186)(a)	$	392	$	—	$	—	$	392

Total assets	392		—		—		392
Liabilities
Deferred compensation obligation (Accounts 228.3, 242)	—		(8)		—		(8)
Commodity liabilities(b) (Accounts 242, 253)	—		—		(84)		(84)
Total liabilities	—		(8)		(84)		(92)
Total net assets (liabilities)	$	392	$	(8)	$	(84)	$	300

__________

(a)ComEd excludes cash of $46 million and $11 million as of December 31, 2023 and 2022, respectively, and restricted cash of $147 million and $76 million as of December 31, 2023 and 2022, respectively, and includes long-term restricted cash of $174 million and $117 million as of December 31, 2023 and 2022, respectively, which is reported in Other deferred debits in the Balance Sheet. The excluded cash balance as of December 31, 2022 has been updated from the amount previously disclosed in the 2022 FERC Form No. 1.

(b)The Level 3 balance consists of the current and noncurrent liability of $27 million and $106 million, respectively, as of December 31, 2023, and $5 million and $79 million, respectively, as of December 31, 2022 related to floating-to-fixed energy swap contracts with unaffiliated suppliers.

Reconciliation of Level 3 Assets and Liabilities

The following tables present the fair value reconciliation of Level 3 assets and liabilities measured at fair value on a recurring basis during the years ended December 31, 2023 and 2022:


	Mark-to-Market Derivatives
Balance as of December 31, 2022	$	(84)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)	(49)
Balance as of December 31, 2023 (Accounts 242, 253)	$	(133)	(b)


	Mark-to-Market Derivatives
Balance as of December 30, 2021	$	(219)
Total realized / unrealized gains (losses) included in regulatory assets/liabilities(a)	135
Balance as of December 31, 2022 (Accounts 242, 253)	$	(84)

__________

(a)Includes $83 million of decreases in fair value and an increase for realized losses due to settlements of $34 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2023. Includes $136 million of increases in fair value and a decrease for realized losses due to settlements of $1 million recorded in purchased power expense associated with floating-to-fixed energy swap contracts with unaffiliated suppliers for the year ended December 31, 2022.

(b)The balance consists of a current (Account 242) and noncurrent (Account 253) liability of $27 million and $106 million, respectively, as of December 31, 2023.

Valuation Techniques Used to Determine Fair Value

Cash Equivalents. Investments with original maturities of three months or less when purchased, including mutual and money market funds, are considered cash equivalents. The fair values are based on observable market prices and, therefore, are included in the recurring fair value measurements hierarchy as Level 1.

Deferred Compensation Obligations. ComEd’s deferred compensation plan allows participants to defer certain cash compensation into a notional investment account. ComEd includes such plans in other current and noncurrent liabilities in its Balance Sheet. The value of ComEd’s deferred compensation obligations is based on the market value of the participants’ notional investment accounts. The underlying notional investments are comprised primarily of equities, mutual funds, commingled funds, and fixed income securities, which are based on directly and indirectly observable market prices. Since the deferred compensation obligations themselves are not exchanged in an active market, they are categorized as Level 2 in the fair value hierarchy.

The value of certain employment agreement obligations (which are included with the Deferred Compensation Obligation in the tables above) are based on a known and certain stream of payments to be made over time and are categorized as Level 2 within the fair value hierarchy.

Commodity Derivatives. On December 17, 2010, ComEd entered into several 20-year floating to fixed energy swap contracts with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs. Delivery under the contracts began in June 2012. The fair value of these swaps has been designated as a Level 3 valuation due to the long tenure of the positions and the internal modeling assumptions. The modeling assumptions include using forward power prices. See Note 9 — Derivative Financial Instruments for additional information on mark-to-market derivatives. .

The following table presents the significant inputs to the forward curve used to value ComEd’s position:


Type of trade	Fair Value as of December 31, 2023		Valuation Technique	Unobservable Input	2023 Range & Arithmetic Average
Commodity derivatives	$	(133)	Discounted Cash Flow	Forward power price(a)	$30.27	—	$73.71	$43.35

Type of trade	Fair Value as of December 31, 2022		Valuation Technique	Unobservable Input	2022 Range & Arithmetic Average
Commodity derivatives	$	(84)	Discounted Cash Flow	Forward power price(a)	$34.78	—	$75.71	$48.44

__________

(a)An increase to the forward power price would increase the fair value.

12. Commitments and Contingencies

Commercial Commitments

ComEd's commercial commitments as of December 31, 2023, representing commitments potentially triggered by future events, were as follows:


	Expiration within
	Total		2024		2025		2026		2027		2028		2029 and beyond
Letters of credit(a)	$	17	$	15	$	2	$	—	$	—	$	—	$	—
Surety bonds(b)	46		46		—		—		—		—		—
Financing trust guarantees(c)	200		—		—		—		—		—		200
Total commercial commitments	$	263	$	61	$	2	$	—	$	—	$	—	$	200

__________

(a)ComEd maintains non-debt letters of credit to provide credit support for certain transactions as requested by third parties.

(b)Surety bonds—Guarantees issued related to contract and commercial agreements, excluding bid bonds. Historically, payments under the guarantees have not been made and the likelihood of payments being required is remote.

(c)Reflects guarantee of ComEd securities held by ComEd Financing III.

Environmental Remediation Matters

General. ComEd’s operations have in the past, and may in the future, require substantial expenditures to comply with environmental laws. Additionally, under federal and state environmental laws, ComEd is generally liable for the costs of remediating environmental contamination of property now or formerly owned by them and of property contaminated by hazardous substances generated by them. ComEd owns or leases a number of real estate parcels, including parcels on which its operations or the operations of others may have resulted in contamination by substances that are considered hazardous

under environmental laws. In addition, ComEd is currently involved in a number of proceedings relating to sites where hazardous substances have been deposited and may be subject to additional proceedings in the future. Unless otherwise disclosed, ComEd cannot reasonably estimate whether it will incur significant liabilities for additional investigation and remediation costs at these or additional sites identified by ComEd, environmental agencies or others, or whether such costs will be recoverable from third parties, including customers. Additional costs could have a material, unfavorable impact on ComEd's financial statements.

Manufactured Gas Plant (MGP) Sites. ComEd has identified sites where former MGP activities have or may have resulted in actual site contamination. For some sites, there are additional potentially responsible parties that may share responsibility for the ultimate remediation of each location. ComEd has 17 sites that are currently under some degree of active study and/or remediation. ComEd expects the majority of the remediation at these sites to continue through at least 2031.

The historical nature of the MGP sites and the fact that many of the sites have been buried and built over, impacts the ability to determine a precise estimate of the ultimate costs prior to initial sampling and determination of the exact scope and method of remedial activity. Management determines its best estimate of remediation costs using all available information at the time of each study, including probabilistic and deterministic modeling, and the remediation standards currently required by the applicable state environmental agency. Prior to completion of any significant clean up, each site remediation plan is approved by the appropriate state environmental agency.

ComEd, pursuant to an ICC order, is currently recovering environmental remediation costs of former MGP facility sites through customer rates.

In 2023, ComEd completed an annual study of its future estimated MGP remediation requirements. The study resulted in a $25 million increase to the environmental liability and related regulatory asset. The increase was primarily due to increased costs due to inflation and changes in remediation plans.

As of December 31, 2023 and 2022, ComEd had accrued the following undiscounted amounts for environmental liabilities in Account 228.4, Accumulated Miscellaneous Operating Provisions in its Balance Sheet:


	Total Environmental Investigation and Remediation Liabilities		Portion of Total Related to MGP Investigation and Remediation
December 31, 2023	$	303	$	302
December 31, 2022	$	325	$	324

Litigation and Regulatory Matters

Fund Transfer Restrictions. Under applicable law, ComEd can pay dividends only from retained, undistributed or current earnings. A significant loss recorded at ComEd may limit the dividends that can distribute to Exelon.

ComEd has agreed in connection with financings arranged through ComEd Financing III that it will not declare dividends on any shares of its capital stock in the event that: (1) it exercises its right to extend the interest payment periods on the subordinated debt securities issued to ComEd Financing III; (2) it defaults on its guarantee of the payment of distributions on the preferred trust securities of ComEd Financing III; or (3) an event of default occurs under the Indenture under which the subordinated debt securities are issued. No such event has occurred.

Deferred Prosecution Agreement (DPA) and Related Matters. Exelon and ComEd received a grand jury subpoena in the second quarter of 2019 from the United States Attorney's Office for the Northern District of Illinois (USAO) requiring production of information concerning their lobbying activities in the State of Illinois. On October 4, 2019, Exelon and ComEd received a second grand jury subpoena from the USAO requiring production of records of any communications with certain individuals and entities. On October 22, 2019, the SEC notified Exelon and ComEd that it had also opened an investigation into their lobbying activities. On July 17, 2020, ComEd entered into a DPA with the USAO to resolve the USAO investigation. Under the DPA, the USAO filed a single charge alleging that ComEd improperly gave and offered to give jobs, vendor subcontracts, and payments associated with those jobs and subcontracts for the benefit of the former Speaker of the Illinois House of Representatives and the Speaker’s associates, with the intent to influence the Speaker’s action regarding legislation affecting ComEd’s interests. The DPA provided that the USAO would defer any prosecution of such charge and any other criminal or civil case against ComEd in connection with the matters identified therein for a three-year period subject to certain obligations of ComEd, including payment to the U.S. Treasury of $200 million, which was paid in November 2020. Exelon was not made a party to the DPA, and therefore the investigation by the USAO into Exelon’s activities ended with no charges being brought against Exelon. The three-year term of the DPA ended on July 17, 2023, and on that same date the court granted the USAO’s motion to dismiss the pending charge against ComEd that had been deferred by the DPA.

On September 28, 2023, Exelon and ComEd reached a settlement with the Securities and Exchange Commission (SEC), concluding and resolving in its entirety the SEC investigation, which related to the conduct identified in the DPA that was

entered into by ComEd in July 2020 and successfully exited in July 2023. Under the terms of the settlement, Exelon agreed to pay a civil penalty of $46.2 million and Exelon and ComEd agreed to cease and desist from committing or causing any violations and any future violations of specified provisions of the federal securities laws and rules promulgated thereunder. Exelon recorded an accrual for the full amount of the penalty in the second quarter of 2023, which was reflected in Operating and maintenance expense within Exelon's Consolidated Statements of Operations and Comprehensive Income and in Accrued expenses on the Consolidated Balance Sheets. Exelon paid the civil penalty in full on October 4, 2023.

Subsequent to Exelon announcing the receipt of the subpoenas, various lawsuits were filed, and various demand letters were received, related to the subject of the subpoenas and the conduct described in the DPA and the SEC's investigation, including:

•Four putative class action lawsuits against ComEd and Exelon were filed in federal court on behalf of ComEd customers in the third quarter of 2020 alleging, among other things, civil violations of federal racketeering laws. In addition, the Citizens Utility Board (CUB) filed a motion to intervene in these cases on October 22, 2020 which was granted on December 23, 2020. On September 9, 2021, the federal court granted Exelon’s and ComEd’s motion to dismiss and dismissed the plaintiffs’ and CUB’s federal law claim with prejudice. The federal court also dismissed the related state law claims made by the federal plaintiffs and CUB on jurisdictional grounds. Plaintiffs appealed dismissal of the federal law claim to the Seventh Circuit Court of Appeals. Plaintiffs and CUB also refiled their state law claims in state court and moved to consolidate them with the already pending consumer state court class action, discussed below. On August 22, 2022, the Seventh Circuit affirmed the dismissal of the consolidated federal cases in their entirety. The time to further appeal has passed and the Seventh Circuit’s decision is final.

•Three putative class action lawsuits against ComEd and Exelon were filed in Illinois state court in the third quarter of 2020 seeking restitution and compensatory damages on behalf of ComEd customers. The cases were consolidated into a single action in October of 2020. In November 2020, CUB filed a motion to intervene in the cases pursuant to an Illinois statute allowing CUB to intervene as a party or otherwise participate on behalf of utility consumers in any proceeding which affects the interest of utility consumers. On November 23, 2020, the court allowed CUB’s intervention, but denied CUB's request to stay these cases. Plaintiffs subsequently filed a consolidated complaint, and ComEd and Exelon filed a motion to dismiss on jurisdictional and substantive grounds on January 11, 2021. Briefing on that motion was completed on March 2, 2021. The parties agreed, on March 25, 2021, along with the federal court plaintiffs discussed above, to jointly engage in mediation. The parties participated in a one-day mediation on June 7, 2021 but no settlement was reached. On December 23, 2021, the state court granted ComEd and Exelon’s motion to dismiss with prejudice. On December 30, 2021, plaintiffs filed a motion to reconsider that dismissal and for permission to amend their complaint. The court denied the plaintiffs' motion on January 21, 2022. Plaintiffs have appealed the court's ruling dismissing their complaint to the First District Court of Appeals. On February 15, 2022, Exelon and ComEd moved to dismiss the federal plaintiffs' refiled state law claims, seeking dismissal on the same legal grounds asserted in their motion to dismiss the original state court plaintiffs' complaint. The court granted dismissal of the refiled state claims on February 16, 2022. The original federal plaintiffs appealed that dismissal on February 18, 2022. The two state appeals were consolidated on March 21, 2022. On September 8, 2023, the Illinois appellate court affirmed the dismissal. Plaintiffs have asked the Illinois Supreme Court to grant them leave to further appeal, but such appeal is not allowed as a matter of right. Exelon and ComEd filed a response in opposition to the request for leave to further appeal on January 12, 2024.

•On November 3, 2022, a plaintiff filed a putative class action complaint in Lake County, Illinois Circuit Court against ComEd and Exelon for unjust enrichment and deceptive business practices in connection with the conduct giving rise to the DPA. Plaintiff seeks an accounting and disgorgement of any benefits ComEd allegedly obtained from said conduct. Plaintiff served initial discovery requests on ComEd in December 2022, to which ComEd has responded. ComEd and Exelon filed a motion to dismiss the Complaint on February 3, 2023. On June 16, 2023, the court granted Exelon and ComEd's motion to dismiss the action with prejudice. Plaintiff filed its notice of appeal of that dismissal on July 17, 2023. Plaintiff's opening appellate brief was filed on October 19, 2023. ComEd and Exelon filed a response on January 2, 2024. Plaintiff filed its reply brief on February 2, 2024. With leave of court, Exelon and ComEd filed a sur-reply on February 14, 2024. The appellate court has set oral argument for April 3, 2024.

•A putative class action lawsuit against Exelon and certain officers of Exelon and ComEd was filed in federal court in December 2019 alleging misrepresentations and omissions in Exelon’s SEC filings related to ComEd’s lobbying activities and the related investigations. The complaint was amended on September 16, 2020, to dismiss two of the original defendants and add other defendants, including ComEd. Defendants filed a motion to dismiss in November 2020. The court denied the motion in April 2021. On May 26, 2021, defendants moved the court to certify its order denying the motion to dismiss for interlocutory appeal. Briefing on the motion was completed in June 2021, and that motion was denied on January 28, 2022. In May 2021, the parties each filed respective initial discovery disclosures. On June 9, 2021, defendants filed their answer and affirmative defenses to the complaint and the parties engaged thereafter in discovery. On September 9, 2021, the U.S. government moved to intervene in the lawsuit and stay

discovery until the parties entered into an amendment to their protective order that would prohibit the parties from requesting discovery into certain matters, including communications with the U.S. government. The court ordered said amendment to the protective order on November 15, 2021 and discovery resumed. The court further amended the protective order on October 17, 2022 and extended it until May 15, 2023. Following mediation, the parties reached a settlement of the lawsuit, under which defendants agreed to pay plaintiffs $173 million. On May 26, 2023, plaintiffs filed a motion for preliminary approval of the settlement, which the court granted on June 9, 2023. The court granted final settlement approval on September 7, 2023. The settlement was fully covered by insurance and has been paid in full.

•Several shareholders have sent letters to the Exelon Board of Directors since 2020 demanding, among other things, that the Exelon Board of Directors investigate and address alleged breaches of fiduciary duties and other alleged violations by Exelon and ComEd officers and directors related to the conduct described in the DPA. In the first quarter of 2021, the Exelon Board of Directors appointed a Special Litigation Committee (SLC) consisting of disinterested and independent parties to investigate and address these shareholders' allegations and make recommendations to the Exelon Board of Directors based on the outcome of the SLC's investigation. In July 2021, one of the demand letter shareholders filed a derivative action against current and former Exelon and ComEd officers and directors, and against Exelon, as nominal defendant, asserting the same claims made in its demand letter. On October 12, 2021, the parties to the derivative action filed an agreed motion to stay that litigation for 120 days in order to allow the SLC to continue its investigation, which the court granted. The stay has been extended several times. The parties participated in a mediation in February 2023, but the matter did not resolve at that time. On April 26 and May 1, 2023, two additional demand letter shareholders each filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and certain third parties, and against Exelon as nominal defendant, asserting claims similar to those made in their respective demand letters. On May 25, 2023, certain demand letter shareholders (Settling Shareholders) filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and against Exelon as nominal defendant, asserting claims similar to those made in their respective demand letters. The then pending derivative lawsuits were subsequently consolidated. On May 26, 2023, prior to lawsuit consolidation, the SLC filed a Notice of Determination and Intent to Seek Court Approval of Settlement (Notice of Determination). The Notice of Determination stated that, through mediation efforts, a settlement of the derivative claims had been approved by the SLC, the Independent Review Committee of the Board (which had been formed in the third quarter of 2022, to ensure the Board’s consideration of any SLC recommendations would be independent and objective), the Board, and the Settling Shareholders (the Settling Parties). The Notice of Determination further specified the process by which the Settling Parties would seek court approval of the proposed settlement and resolution and dismissal of all derivative claims and lawsuits, including any lawsuits or actions brought by demand letter shareholders who are not participating in the proposed settlement. In furtherance of the proposed settlement, on June 16, 2023, the SLC filed a motion for preliminary approval of the settlement, attaching the Stipulation and Agreement of Settlement (Stipulation), which contains the terms of the proposed settlement. The proposed settlement terms include but are not limited to: a payment of $40 million to Exelon by Exelon’s insurers of which $10 million constitutes the attorneys’ fee award to be paid to the Settling Shareholders’ counsel; various compliance and disclosure-related reforms; and certain changes in Board and Committee composition. On June 13, 2023, the non-settling derivative shareholders filed a motion asking the court to set a status conference to discuss lifting the discovery stay. On June 29, 2023, an additional shareholder filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and against Exelon as nominal defendant, asserting claims similar to those made in its demand letter. That lawsuit has been consolidated into the other pending derivative lawsuits. On June 30, 2023, the non-settling shareholders’ motion for status and the SLC’s motion for preliminary approval was heard by the court, during which the court set a briefing schedule on the appropriate standard for evaluating the settlement and the proper scope of requested discovery. Following briefing and a hearing, the court allowed the non-settling shareholders to seek certain, limited discovery, which the SLC, Independent Review Committee, and Exelon responded to on October 5, 2023. On October 11, 2023, an additional non-settling shareholder filed a separate derivative lawsuit against current and former Exelon and ComEd officers and directors, and against Exelon as a nominal defendant, asserting claims similar to those made in its demand letter. That lawsuit has been consolidated into the other pending derivative lawsuits. The SLC filed its renewed motion for preliminary approval on October 26, 2023, with supporting submissions filed by the Independent Review Committee, Exelon, and the settling shareholders on that same day. The non-settling plaintiffs filed a response to the renewed motion for preliminary approval and supporting submissions on November 29, 2023, and the SLC Independent Review Committee, Exelon and the Settling Shareholders filed their respective reply briefs on December 21, 2023. On January 16, 2024, the non-settling plaintiffs sought leave of court to file a sur-reply, which the court granted on January 18, 2024.

In August 2022, the ICC concluded its investigation initiated on August 12, 2021 into rate impacts of conduct admitted in the DPA, including the costs recovered from customers related to the DPA and Exelon's funding of the fine paid by ComEd. On August 17, 2022, the ICC issued its final order accepting ComEd's voluntary customer refund offer of approximately $38 million (of which about $31 million is ICC jurisdictional; the remaining balance is FERC jurisdictional) that resolves the

question of whether customer funds were used for DPA related activities. The customer refund includes the cost of every individual or entity that was either (i) identified in the DPA or (ii) identified by ComEd as an associate of the former Speaker of the Illinois House of Representatives in the ICC proceeding. The ICC’s DPA investigation is now closed. The ICC jurisdictional refund was made to customers during the April 2023 billing cycle, as required by the ICC. The FERC jurisdictional refund was included in ComEd's transmission formula rate update proceeding, filed on May 12, 2023. The filed transmission rate, inclusive of the FERC jurisdictional DPA refund, will appear on ComEd retail customers' bills for the June 2023 through May 2024 monthly billing periods, in the line designated as "Transmission Services Charge." The customer refund will not be recovered in rates or charged to customers and ComEd will not seek or accept reimbursement or indemnification from any source other than Exelon. An accrual for the amount of the customer refund has been recorded in Regulatory assets (account 182.3) and Regulatory liabilities (account 254) in Exelon’s and ComEd’s Consolidated Balance Sheets as of December 31, 2023.

General. ComEd is involved in various other litigation matters that are being defended and handled in the ordinary course of business. ComEd is also from time to time subject to audits and investigations by the FERC and other regulators. The assessment of whether a loss is probable or reasonably possible, and whether the loss or a range of loss is estimable, often involves a series of complex judgments about future events. ComEd maintains accruals for such losses that are probable of being incurred and subject to reasonable estimation. Management is sometimes unable to estimate an amount or range of reasonably possible loss, particularly where (1) the damages sought are indeterminate, (2) the proceedings are in the early stages, or (3) the matters involve novel or unsettled legal theories. In such cases, there is considerable uncertainty regarding the timing or ultimate resolution of such matters, including a possible eventual loss.

13. Shareholders' Equity

Common Stock Warrants (Account 201)

ComEd had 60,032 and 60,052 warrants outstanding to purchase ComEd common stock at December 31, 2023 and 2022, respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2023 and 2022, 20,011 and 20,017 shares of common stock, respectively, were reserved for the conversion of warrants.

Preferred and Preference Securities (Account 204)

At December 31, 2023 and 2022, ComEd had preferred securities and cumulative preference securities of 850,000 shares and 6,810,451 shares authorized, respectively, none of which were outstanding.

14. Supplemental Financial Information

Supplemental Statement of Income Information

The following table provides additional information about material items recorded in ComEd's Statement of Income for the years ended December 31, 2023 and 2022:


	For the Year Ended December 31,
	2023		2022
Taxes other than income (Accounts 408.1 and 408.2)
Utility(a)	$	299	$	306
Property	33		31
Payroll	31		28

________

(a)ComEd’s utility taxes represent municipal and state utility taxes and gross receipts taxes related to its operating revenues. The offsetting collection of utility taxes from customers is recorded in revenues in ComEd's Statement of Income.

Supplemental Statement of Cash Flows Information

The following table provides additional information about ComEd's Statement of Cash Flows for the years ended December 31, 2023 and 2022:


	For the Year Ended December 31,
	2023		2022
Cash paid during the year
Interest (net of amount capitalized)	$	441	$	396
Income Taxes (net of refunds)	11		23

Non-cash investing activities
Decrease in capital expenditures not paid	$	(10)	$	(20)

15. Related Party Transactions

Expenses from Generation

ComEd incurred expenses from transaction with the Generation affiliate as described in the footnote to the table below prior to the separation on February 1, 2022. Such expenses were primarily recorded as Purchased power from affiliates and an immaterial amount recorded as Operating and maintenance expense from affiliates at ComEd. Effective February 1, 2022, Generation is no longer considered a related party of ComEd.

ComEd's Purchased power from Generation are as follows:


	For the Years Ended December 31,
	2022
Expenses with Generation(a)	$	59

__________

(a) ComEd had an ICC approved RFP contract with Generation to provide a portion of ComEd's electric supply requirements. ComEd also purchased RECs and ZECs from Generation

Service Company Costs for Corporate Support

ComEd receives a variety of corporate support services from Exelon's Business Services Corporation (BSC). The following table presents the service company costs allocated to ComEd:


	Operating and maintenance from affiliate				Capitalized costs from affiliate
	For the years ended December 31,				As of December 31,
	2023		2022		2023		2022
BSC	$	353	$	316	$	307	$	311

Current Payables to affiliates

The following table presents ComEd's current Payables to affiliates:


	As of December 31,
	2023		2022



BSC	$	64	$	66
ComEd Financing III	4		4

ComEd of Indiana	1		—




Other	4		4
Total	$	73	$	74

Noncurrent Receivables from affiliates

The following table presents ComEd's noncurrent Receivables from affiliates:


	For the Years Ended December 31,
	2023		2022(a)


Other(a)	$	3	$	3

__________

(a) The December 31, 2022 noncurrent receivables from affiliates balance was classified as both current and noncurrent receivables from affiliates in the 2022 Form 1 filed April 4, 2023. The December 31, 2022 balance has been corrected and the current receivables from affiliates table has been removed from the footnote above.

Long-term debt to financing trusts

ComEd has Long-term debt to the ComEd Financing III trust of $205 million as of both December 31, 2023 and 2022.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

STATEMENTS OF ACCUMULATED COMPREHENSIVE INCOME, COMPREHENSIVE INCOME, AND HEDGING ACTIVITIES
Report in columns (b),(c),(d) and (e) the amounts of accumulated other comprehensive income items, on a net-of-tax basis, where appropriate. Report in columns (f) and (g) the amounts of other categories of other cash flow hedges. For each category of hedges that have been accounted for as "fair value hedges", report the accounts affected and the related amounts in a footnote. Report data on a year-to-date basis.
Line No.	Item (a)	Unrealized Gains and Losses on Available-For-Sale Securities (b)	Minimum Pension Liability Adjustment (net amount) (c)	Foreign Currency Hedges (d)	Other Adjustments (e)	Other Cash Flow Hedges Interest Rate Swaps (f)	Other Cash Flow Hedges [Specify] (g)	Totals for each category of items recorded in Account 219 (h)	Net Income (Carried Forward from Page 116, Line 78) (i)	Total Comprehensive Income (j)
1	Balance of Account 219 at Beginning of Preceding Year
2	Preceding Quarter/Year to Date Reclassifications from Account 219 to Net Income
3	Preceding Quarter/Year to Date Changes in Fair Value
4	Total (lines 2 and 3)								917,177,045	917,177,045
5	Balance of Account 219 at End of Preceding Quarter/Year
6	Balance of Account 219 at Beginning of Current Year
7	Current Quarter/Year to Date Reclassifications from Account 219 to Net Income
8	Current Quarter/Year to Date Changes in Fair Value
9	Total (lines 7 and 8)								1,094,078,343	1,094,078,343
10	Balance of Account 219 at End of Current Quarter/Year

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SUMMARY OF UTILITY PLANT AND ACCUMULATED PROVISIONS FOR DEPRECIATION. AMORTIZATION AND DEPLETION
Report in Column (c) the amount for electric function, in column (d) the amount for gas function, in column (e), (f), and (g) report other (specify) and in column (h) common function.
Line No.	Classification (a)	Total Company For the Current Year/Quarter Ended (b)	Electric (c)	Gas (d)	Other (Specify) (e)	Other (Specify) (f)	Other (Specify) (g)	Common (h)
1	UtilityPlantAbstract UTILITY PLANT
2	UtilityPlantInServiceAbstract In Service
3	UtilityPlantInServiceClassified Plant in Service (Classified)	36,318,993,336	36,318,993,336
4	UtilityPlantInServicePropertyUnderCapitalLeases Property Under Capital Leases	7,849,772	7,849,772
5	UtilityPlantInServicePlantPurchasedOrSold Plant Purchased or Sold
6	UtilityPlantInServiceCompletedConstructionNotClassified Completed Construction not Classified	1,124,503,119	1,124,503,119
7	UtilityPlantInServiceExperimentalPlantUnclassified Experimental Plant Unclassified
8	UtilityPlantInServiceClassifiedAndUnclassified Total (3 thru 7)	37,451,346,227	37,451,346,227
9	UtilityPlantLeasedToOthers Leased to Others
10	UtilityPlantHeldForFutureUse Held for Future Use	89,342,102	89,342,102
11	ConstructionWorkInProgress Construction Work in Progress	1,395,544,738	1,395,544,738
12	UtilityPlantAcquisitionAdjustment Acquisition Adjustments	2,774,314,255	2,774,314,255
13	UtilityPlantAndConstructionWorkInProgress Total Utility Plant (8 thru 12)	41,710,547,322	41,710,547,322
14	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Accumulated Provisions for Depreciation, Amortization, & Depletion	11,713,097,084	11,713,097,084
15	UtilityPlantNet Net Utility Plant (13 less 14)	29,997,450,238	29,997,450,238
16	DetailOfAccumulatedProvisionsForDepreciationAmortizationAndDepletionAbstract DETAIL OF ACCUMULATED PROVISIONS FOR DEPRECIATION, AMORTIZATION AND DEPLETION
17	AccumulatedProvisionForDepreciationAmortizationAndDepletionUtilityPlantInServiceAbstract In Service:
18	DepreciationUtilityPlantInService Depreciation	10,663,341,920	10,663,341,920
19	AmortizationAndDepletionOfProducingNaturalGasLandAndLandRightsutilityPlantInService Amortization and Depletion of Producing Natural Gas Land and Land Rights
20	AmortizationOfUndergroundStorageLandAndLandRightsutilityPlantInService Amortization of Underground Storage Land and Land Rights
21	AmortizationOfOtherUtilityPlantUtilityPlantInService Amortization of Other Utility Plant	900,380,549	900,380,549
22	DepreciationAmortizationAndDepletionUtilityPlantInService Total in Service (18 thru 21)	11,563,722,469	11,563,722,469
23	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthersAbstract Leased to Others
24	DepreciationUtilityPlantLeasedToOthers Depreciation
25	AmortizationAndDepletionUtilityPlantLeasedToOthers Amortization and Depletion
26	DepreciationAmortizationAndDepletionUtilityPlantLeasedToOthers Total Leased to Others (24 & 25)
27	DepreciationAndAmortizationUtilityPlantHeldForFutureUseAbstract Held for Future Use
28	DepreciationUtilityPlantHeldForFutureUse Depreciation
29	AmortizationUtilityPlantHeldForFutureUse Amortization
30	DepreciationAndAmortizationUtilityPlantHeldForFutureUse Total Held for Future Use (28 & 29)
31	AbandonmentOfLeases Abandonment of Leases (Natural Gas)
32	AmortizationOfPlantAcquisitionAdjustment Amortization of Plant Acquisition Adjustment	149,374,615	149,374,615
33	AccumulatedProvisionForDepreciationAmortizationAndDepletionOfPlantUtility Total Accum Prov (equals 14) (22,26,30,31,32)	11,713,097,084	11,713,097,084

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

NUCLEAR FUEL MATERIALS (Account 120.1 through 120.6 and 157)
Report below the costs incurred for nuclear fuel materials in process of fabrication, on hand, in reactor, and in cooling; owned by the respondent. If the nuclear fuel stock is obtained under leasing arrangements, attach a statement showing the amount of nuclear fuel leased, the quantity used and quantity on hand, and the costs incurred under such leasing arrangements.
Line No.	Description of item (a)	Balance Beginning of Year (b)	Changes during Year Additions (c)	Changes during Year Amortization (d)	Changes during Year Other Reductions (Explain in a footnote) (e)	Balance End of Year (f)
1	Nuclear Fuel in process of Refinement, Conv, Enrichment & Fab (120.1)
2	Fabrication
3	Nuclear Materials
4	Allowance for Funds Used during Construction
5	(Other Overhead Construction Costs, provide details in footnote)
6	SUBTOTAL (Total 2 thru 5)
7	Nuclear Fuel Materials and Assemblies
8	In Stock (120.2)
9	In Reactor (120.3)
10	SUBTOTAL (Total 8 & 9)
11	Spent Nuclear Fuel (120.4)
12	Nuclear Fuel Under Capital Leases (120.6)
13	(Less) Accum Prov for Amortization of Nuclear Fuel Assem (120.5)
14	TOTAL Nuclear Fuel Stock (Total 6, 10, 11, 12, less 13)
15	Estimated Net Salvage Value of Nuclear Materials in Line 9
16	Estimated Net Salvage Value of Nuclear Materials in Line 11
17	Est Net Salvage Value of Nuclear Materials in Chemical Processing
18	Nuclear Materials held for Sale (157)
19	Uranium
20	Plutonium
21	Other (Provide details in footnote)
22	TOTAL Nuclear Materials held for Sale (Total 19, 20, and 21)

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ELECTRIC PLANT IN SERVICE (Account 101, 102, 103 and 106)
Report below the original cost of electric plant in service according to the prescribed accounts. In addition to Account 101, Electric Plant in Service (Classified), this page and the next include Account 102, Electric Plant Purchased or Sold; Account 103, Experimental Electric Plant Unclassified; and Account 106, Completed Construction Not Classified-Electric. Include in column (c) or (d), as appropriate, corrections of additions and retirements for the current or preceding year. For revisions to the amount of initial asset retirement costs capitalized, included by primary plant account, increases in column (c) additions and reductions in column (e) adjustments. Enclose in parentheses credit adjustments of plant accounts to indicate the negative effect of such accounts. Classify Account 106 according to prescribed accounts, on an estimated basis if necessary, and include the entries in column (c). Also to be included in column (c) are entries for reversals of tentative distributions of the prior year reported in column (b). Likewise, if the respondent has a significant amount of plant retirements which have not been classified to primary accounts at the end of the year, include in column (d) a tentative distribution of such retirements, on an estimated basis, with appropriate contra entry to the account for accumulated depreciation provision. Include also in column (d) distributions of these tentative classifications in columns (c) and (d), including the reversals of the prior years tentative account distributions of these amounts. Careful observance of the above instructions and the texts of Accounts 101 and 106 will avoid serious omissions of the reported amount of respondent’s plant actually in service at end of year. Show in column (f) reclassifications or transfers within utility plant accounts. Include also in column (f) the additions or reductions of primary account classifications arising from distribution of amounts initially recorded in Account 102, include in column (e) the amounts with respect to accumulated provision for depreciation, acquisition adjustments, etc., and show in column (f) only the offset to the debits or credits distributed in column (f) to primary account classifications. For Account 399, state the nature and use of plant included in this account and if substantial in amount submit a supplementary statement showing subaccount classification of such plant conforming to the requirement of these pages. For each amount comprising the reported balance and changes in Account 102, state the property purchased or sold, name of vendor or purchase, and date of transaction. If proposed journal entries have been filed with the Commission as required by the Uniform System of Accounts, give also date.
Line No.	Account (a)	Balance Beginning of Year (b)	Additions (c)	Retirements (d)	Adjustments (e)	Transfers (f)	Balance at End of Year (g)
1	1. INTANGIBLE PLANT
2	(301) Organization	80,375					80,375
3	(302) Franchise and Consents
4	(303) Miscellaneous Intangible Plant	1,107,589,922	103,990,093	39,061,493			1,172,518,522
5	TOTAL Intangible Plant (Enter Total of lines 2, 3, and 4)	1,107,670,297	103,990,093	39,061,493			1,172,598,897
6	2. PRODUCTION PLANT
7	A. Steam Production Plant
8	(310) Land and Land Rights
9	(311) Structures and Improvements
10	(312) Boiler Plant Equipment
11	(313) Engines and Engine-Driven Generators
12	(314) Turbogenerator Units
13	(315) Accessory Electric Equipment
14	(316) Misc. Power Plant Equipment
15	(317) Asset Retirement Costs for Steam Production
16	TOTAL Steam Production Plant (Enter Total of lines 8 thru 15)
17	B. Nuclear Production Plant
18	(320) Land and Land Rights
19	(321) Structures and Improvements
20	(322) Reactor Plant Equipment
21	(323) Turbogenerator Units
22	(324) Accessory Electric Equipment
23	(325) Misc. Power Plant Equipment
24	(326) Asset Retirement Costs for Nuclear Production
25	TOTAL Nuclear Production Plant (Enter Total of lines 18 thru 24)
26	C. Hydraulic Production Plant
27	(330) Land and Land Rights
28	(331) Structures and Improvements
29	(332) Reservoirs, Dams, and Waterways
30	(333) Water Wheels, Turbines, and Generators
31	(334) Accessory Electric Equipment
32	(335) Misc. Power Plant Equipment
33	(336) Roads, Railroads, and Bridges
34	(337) Asset Retirement Costs for Hydraulic Production
35	TOTAL Hydraulic Production Plant (Enter Total of lines 27 thru 34)
36	D. Other Production Plant
37	(340) Land and Land Rights
38	(341) Structures and Improvements
39	(342) Fuel Holders, Products, and Accessories
40	(343) Prime Movers
41	(344) Generators
42	(345) Accessory Electric Equipment
43	(346) Misc. Power Plant Equipment
44	(347) Asset Retirement Costs for Other Production
44.1	(348) Energy Storage Equipment - Production
45	TOTAL Other Prod. Plant (Enter Total of lines 37 thru 44)
46	TOTAL Prod. Plant (Enter Total of lines 16, 25, 35, and 45)
47	3. Transmission Plant
48	(350) Land and Land Rights	189,527,512				30	189,527,542
48.1	(351) Energy Storage Equipment - Transmission
49	(352) Structures and Improvements	758,230,883	36,060,175	4,984,080			789,306,978
50	(353) Station Equipment	2,965,570,121	181,414,030	5,183,058		201,282	3,142,002,375
51	(354) Towers and Fixtures	269,881,353	2,316,895				272,198,248
52	(355) Poles and Fixtures	964,651,855	16,883,156	178,897			981,356,114
53	(356) Overhead Conductors and Devices	676,638,392	28,088,318	574,730			704,151,980
54	(357) Underground Conduit	230,612,808	1,293,915	1,026			231,905,697
55	(358) Underground Conductors and Devices	565,592,514	1,497,762	600,331			563,494,421
56	(359) Roads and Trails	11,259,778	9,461,280				20,721,058
57	(359.1) Asset Retirement Costs for Transmission Plant	4,386,166		87,345	3,281,239		7,580,060
58	TOTAL Transmission Plant (Enter Total of lines 48 thru 57)	6,636,351,382	274,020,007	11,609,467	3,281,239	201,312	6,902,244,473
59	4. Distribution Plant
60	(360) Land and Land Rights	75,592,744				458,608	76,051,352
61	(361) Structures and Improvements	861,665,011	49,832,151	3,318,132		1,505,836	906,673,194
62	(362) Station Equipment	3,891,202,891	192,651,501	26,582,156		9,448,339	4,066,720,575
63	(363) Energy Storage Equipment – Distribution	639,173	364,469				274,704
64	(364) Poles, Towers, and Fixtures	2,781,652,581	271,039,419	25,071,173			3,027,620,827
65	(365) Overhead Conductors and Devices	4,178,819,538	446,219,108	96,906,283			4,528,132,363
66	(366) Underground Conduit	1,118,228,649	19,566,751	1,422,764			1,136,372,636
67	(367) Underground Conductors and Devices	7,725,708,874	522,088,455	48,687,814			8,199,109,515
68	(368) Line Transformers	1,576,826,539	98,754,637	37,654,126		8,143,785	1,629,783,265
69	(369) Services	1,445,845,133	33,780,802	4,431,730			1,475,194,205
70	(370) Meters	839,144,653	19,789,392	860,513			858,073,532
71	(371) Installations on Customer Premises	85,051,136	6,124,567	1,370,277			89,805,426
72	(372) Leased Property on Customer Premises	860,869	36,866				824,003
73	(373) Street Lighting and Signal Systems	209,840,585	7,295,907	6,938,283			210,198,209
74	(374) Asset Retirement Costs for Distribution Plant	45,151,168		229,774	11,009,611		33,911,783
75	TOTAL Distribution Plant (Enter Total of lines 60 thru 74)	24,836,229,544	1,666,741,355	253,473,025	11,009,611	257,326	26,238,745,589
76	5. REGIONAL TRANSMISSION AND MARKET OPERATION PLANT
77	(380) Land and Land Rights
78	(381) Structures and Improvements
79	(382) Computer Hardware
80	(383) Computer Software
81	(384) Communication Equipment
82	(385) Miscellaneous Regional Transmission and Market Operation Plant
83	(386) Asset Retirement Costs for Regional Transmission and Market Oper
84	TOTAL Transmission and Market Operation Plant (Total lines 77 thru 83)
85	6. General Plant
86	(389) Land and Land Rights	38,257,677	10				38,257,667
87	(390) Structures and Improvements	773,123,486	49,335,650	6,261,100			816,198,036
88	(391) Office Furniture and Equipment	162,851,779	29,218,220	23,507,768			168,562,231
89	(392) Transportation Equipment	453,114,856	39,625,876	10,773,501			481,967,231
90	(393) Stores Equipment	8,264,150					8,264,150
91	(394) Tools, Shop and Garage Equipment	270,646,440	12,317,809	179,348			282,784,901
92	(395) Laboratory Equipment	17,246,842	281,216				17,528,058
93	(396) Power Operated Equipment	7,865,504	124,530				7,740,974
94	(397) Communication Equipment	1,199,042,326	75,639,202	3,123,943			(c) 1,271,557,585
95	(398) Miscellaneous Equipment	19,396,592	4,311,879				23,708,471
96	SUBTOTAL (Enter Total of lines 86 thru 95)	2,949,809,652	210,605,312	43,845,660			3,116,569,304
97	(399) Other Tangible Property
98	(399.1) Asset Retirement Costs for General Plant	9,208,109		197,511	4,327,594		13,338,192
99	TOTAL General Plant (Enter Total of lines 96, 97, and 98)	2,959,017,761	210,605,312	44,043,171	4,327,594		3,129,907,496
100	TOTAL (Accounts 101 and 106)	35,539,268,984	2,255,356,767	348,187,156	3,400,778	458,638	37,443,496,455
101	(102) Electric Plant Purchased (See Instr. 8)
102	(Less) (102) Electric Plant Sold (See Instr. 8)
103	(103) Experimental Plant Unclassified
104	TOTAL Electric Plant in Service (Enter Total of lines 100 thru 103)	35,539,268,984	2,255,356,767	348,187,156	(a) 3,400,778	(b) 458,638	37,443,496,455

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: ElectricPlantInServiceAdjustments


The plant in-service adjustments of ($3,400,778) is the result of periodic reviews of, and changes to, the Company's asset retirement obligations.

(b) Concept: ElectricPlantInServiceTransfers


Represents net transfers from Account 105 (Plant Held for Future Use) of $458,638 and net transfers to Account 121 (Non-Utility Property) of $0.


Of the balance reported in Account 397 (Communication Equipment) of $1,271,557,585 - 28.56% of such amount is directly assignable to the Transmission function.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ELECTRIC PLANT LEASED TO OTHERS (Account 104)
Line No.	LesseeName Name of Lessee (a)	IndicationOfAssociatedCompany * (Designation of Associated Company) (b)	LeaseDescription Description of Property Leased (c)	CommissionAuthorization Commission Authorization (d)	ExpirationDateOfLease Expiration Date of Lease (e)	ElectricPlantLeasedToOthers Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ELECTRIC PLANT HELD FOR FUTURE USE (Account 105)
Report separately each property held for future use at end of the year having an original cost of $250,000 or more. Group other items of property held for future use. For property having an original cost of $250,000 or more previously used in utility operations, now held for future use, give in column (a), in addition to other required information, the date that utility use of such property was discontinued, and the date the original cost was transferred to Account 105.
Line No.	ElectricPlantHeldForFutureUseDescription Description and Location of Property (a)	ElectricPlantPropertyClassifiedAsHeldForFutureUseOriginalDate Date Originally Included in This Account (b)	ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate Date Expected to be used in Utility Service (c)	ElectricPlantHeldForFutureUse Balance at End of Year (d)
1	Land and Rights:
2	Transmission Plant (Land and/or Rights):
3	Charter Grove TSS	12/31/2006	(a) 01/01/2030	637,355
4	Cherry Valley-Silver Lake	06/30/1973	01/01/2035	1,827,050
5	Chicago-Northwestern R. R.	12/31/2001	01/01/2032	1,567,260
6	Eakin Creek TSS	09/30/1996	01/01/2035	2,670,479
7	Goodings Grove-Indiana Widening/Crete TSS	09/30/1971	01/01/2032	1,206,117
8	Manville-Pontiac	11/30/1972	01/01/2035	528,398
9	Plano-Charter Grove	06/30/1975	01/01/2035	4,343,302
10	Plato Center - 1	01/31/1992	01/01/2035	426,467
11	Sugar Grove-Blackberry	03/31/1991	01/01/2035	408,473
12	Waukegan Station 354kv Switchyard	12/31/2006	01/01/2035	799,826
13	Wayne-Itasca	12/31/1970	01/01/2035	4,099,384
14	Wilton Center-Joliet	05/31/1973	01/01/2035	352,474
15	Sugar Grove TSS	12/31/2012	01/01/2035	720,587
16	Sawyer TSS	12/31/2019	01/01/2030	441,267
17	18 items less than $250,000 each			1,166,115
18
19
20
21
22
23
24
25
26
27
21	Other Property:
22	Distribution Plant (Land and/or Rights):
23	Plato Center - 2	01/31/1992	01/01/2035	617,255
24	Rutland TDC	09/30/1996	01/01/2035	372,830
25	Lakeview - 1141 W. Diversey	12/01/2020	01/01/2029	11,729,191
26	Land - Aurora to Elgin-Kane	11/01/2021	01/01/2030	41,557,075
27	Plymouth Court	07/31/2022	01/01/2033	4,715,679
28	Jefferson GIS	12/31/2021	01/01/2028	7,718,755
29	29 items less than $250,000			1,428,482
30	General Plant (Land and\or RIghts)
31	1 items less than $250,000			8,281
47	TOTAL			89,342,102

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: ElectricPlantPropertyClassifiedAsHeldForFutureUseExpectedUseInServiceDate


The expected dates to be used in utility service are estimates and are subject to change.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

CONSTRUCTION WORK IN PROGRESS - - ELECTRIC (Account 107)
Report below descriptions and balances at end of year of projects in process of construction (107). Show items relating to "research, development, and demonstration" projects last, under a caption Research, Development, and Demonstrating (see Account 107 of the Uniform System of Accounts). Minor projects (5% of the Balance End of the Year for Account 107 or $1,000,000, whichever is less) may be grouped.
Line No.	ConstructionWorkInProgressProjectDescription Description of Project (a)	ConstructionWorkInProgress Construction work in progress - Electric (Account 107) (b)
1	Intangible Plant
2	Major projects:
3	ComEd/PECO CC&B Impl SW	205,258,941
4	EU GIS CORE SW	32,819,514
5	EU ADMS Implementation SW	29,270,235
6	ADMS SW	26,239,480
7	CEJA CC&B Integration CL CAP	13,914,592
8	ADMS - Cap Software #2 SW	12,034,576
9	Apollo Phase 2 W/O WPT SW	10,814,846
10	Outage Reporting and Analy -CL	8,228,449
11	ADMS RTU Testing SW	5,109,863
12	DER and Load Forecasting SW	3,608,293
13	ComEd IT Virtual FIG Retire SW	3,003,278
14	oneMDS Mobile Dispatch - SW	2,757,657
15	EU GIS DQ SW	2,739,882
16	oneMDS Mobile Dispatch SW RL4	2,532,230
17	PMU Analytics	2,361,418
18	uPPM - ADF SW	2,055,492
19	EU New Business Intellio CL	1,925,230
20	IGA Enhancement Program SW	1,851,081
21	ComEd/PECO CC&B Data Conv SW	1,735,856
22	GIS Transmission SW	1,364,539
23	Urbint (Energy Based) SW	1,149,636
24	CCB INST CONF CCB/MDM BX2 SW	1,079,386
25	Other Projects	(a) 14,715,653
26	Transmission Plant
27	RELO TSS101 Itasca 345kV - GIS	33,069,840
28	TSS 51 McCook 138kV Line	29,363,623
29	TSS 135 Elmhurst 345kV GIS	26,658,369
30	Upgrade 138kV Line 0108	11,193,701
31	TSS 135 Elmhurst Tran Hardn	10,968,550
32	TSS82 CROSBY SEC FENCING	9,641,491
33	CyrusOne Aurora TR at TSS111	4,398,052
34	UA HQ Data Center TSS184	3,805,216
35	TSS46 Des Plaines TR83 Rpl	3,783,621
36	OCC Static Switch Repair	3,498,144
37	INSTALL 3RD TR (40MVA) AT TDC2	3,289,416
38	TSS82 CROSBY SEC TECHNOLOGY	3,187,878
39	Chicago South Switchgear Repla	2,924,645
40	TSS78 Franklin Park L3705 PST	2,446,863
41	TSS 112 Wilton Center 345 kV 5	1,620,018
42	RELO TSS101 Itasca 345kV-Line	1,433,464
43	STA11 Fisk Cap Bank	1,395,105
44	L17105 Wood Pole Replacement	1,371,367
45	TSS112 Ridgeland - TR71 Matrl	1,218,082
46	TSS79 Spaulding TR76 Repl	1,133,998
47	Other Projects - 1	(b) 33,896,939
48	Distribution Plant
49	Major Projects:
50	Project Post TDC214 Expansion	34,170,869
51	5P210005-TSS79 34.5kV bus conf	22,546,371
52	PROJECT MIRACLE GROW	19,528,246
53	Project Post - ESS E 535 - 1	14,540,956
54	Cloud HQ Data Center-ESSE410	10,913,712
55	L17105 Wood Pole Replac	10,841,038
56	Project Post ESS	10,171,418
57	L19202 HPFF Replacement	9,379,986
58	8P230001 - TDC469 40MVA TR	8,926,835
59	Project Circle ESSE552	8,045,328
60	3P190201-Z11884	7,936,757
61	L1863/L1864/L1865 Relocation	7,060,725
62	L15625 Wood Pole Replacement	6,761,859
63	Indirects-Removal for Budget	6,613,244
64	TSS64 Bellwood 12kV Switchgear	6,021,434
65	TSS104 Ford City Intel Sub	5,699,557
66	Project Post - L21408	5,673,160
67	CULLINAN NEW FEEDER	5,481,543
68	Air Liquide New Feeder	5,476,087
69	L13349 Reconductor/Relocation	5,474,730
70	4P223700-DCE27 Arlington Hts’	5,197,105
71	78624 : Franklin Ave OH Reloca	5,094,974
72	TSS 82 Crosby Intel Sub	4,931,679
73	L7542 Customer Count	4,704,374
74	IP2 PCKT RELIABILITY-FDR H261	4,605,240
75	Retire 4kV Fdrs W405 W406 W438	4,525,266
76	Project Post - L21403	4,372,063
77	L19203 HPFF Replacement	4,024,477
78	1P240005-install 5th 50MVA TR	3,740,947
79	Aligned Data Cented 505 NW	3,645,767
80	34kV L13349 Rock Falls	3,191,517
81	BCM Controlled Generation	2,991,909
82	ESSG314 Christ Hospital	2,968,144
83	5P2302: new feeder D3429	2,945,146
84	Spare TR67MVA (3-Wind)Aligned	2,897,131
85	New Feeder Z17449	2,843,878
86	L13349- River Crossing INS CBL	2,834,590
87	McCook IL Joliet Rd	2,824,133
88	8P240200 RLV F5373	2,603,472
89	NORTHPOINT ELWOOD	2,552,518
90	1P190001-Install 5th TR	2,529,276
91	78784 : Canal btwn Madison & T	2,511,610
92	NTT Data Center Phase 2	2,504,733
93	CSX Midway Airport L5103 Reloc	2,503,214
94	SBA EDGE LINE EXTENSION	2,478,399
95	CTA Blue Line Harlem Relo	2,445,321
96	1050 W. Van Buren - Perm	2,366,580
97	4000 W Diversey Perm	2,344,842
98	3P211002-56TH144 12 KV CONV	2,337,340
99	6P230800 - 4:12 conversions	2,279,461
100	Bronzeville Microgrid PMU Inst	2,228,498
101	6001 S Stony Island Ave - OPC	2,213,826
102	CTA Damen Station Perm	2,128,281
103	1P230200: New Feeder Y3037	2,119,841
104	Project Circle NEW ESS	2,116,101
105	TDC556 Berwyn Improvmnt L19202	2,057,354
106	CTA Barry Station Perm	2,047,812
107	12 kV DA Program X4069	2,016,515
108	168 N ABERDEEN PERM	1,952,094
109	34kV Resiliency-L19342 Part 1	1,947,011
110	2021 F.A.U.L.T. Switch Install	1,903,379
111	1112 W CARROLL AVE - PERM	1,819,870
112	12 kV DA Baseline X1492	1,819,284
113	NTT Data Center ESS	1,783,705
114	TSS192 Rdglnd Improvmnt L19202	1,767,824
115	MR 2022 1300 GROUP NETCENTERS	1,682,570
116	110 N Wacker - Cable & Conduit	1,653,219
117	TSS 77 Mazon IP2 Brkr Replace	1,557,103
118	Perm Ser for 808 N. Cleveland	1,550,022
119	TDC785 Ontario PMU Deployment	1,548,527
120	TSS45 Replace TR73	1,529,334
121	IP^2 2021 IP2 - Z13783	1,516,310
122	1P250001-New Rockwell TDC	1,423,306
123	TSS192 Ridgeland TR71 Replcmnt	1,417,333
124	1131-1135 W Winona - Relo	1,416,904
125	2021 REACTS STA13_2 FOH	1,382,394
126	12 kV DA IP2 Y4540	1,379,266
127	2021 REACTS STA13 FOH	1,308,398
128	TSS114 Northwest PMU Deploymnt	1,285,763
129	DCY310 Austin TR1 Replacement	1,266,724
130	87495: NBSW-905,925,999 Belle	1,264,365
131	Christ Hosp Hardening L11567	1,261,694
132	GRIP 2016 12kV Y8256	1,237,023
133	12 kV DA X8442	1,235,869
134	South Elgin Security Technolog	1,229,800
135	Elgin Security Fence	1,210,882
136	28 E Garfield-Washington Park	1,161,132
137	DSS471 Pontiac BT 1-7	1,158,734
138	12 kV DA Baseline 319X246	1,154,279
139	210 N Aberdeen - Perm	1,149,863
140	79657 : IL-71 FROM 0.5MILE EAS	1,137,646
141	8P233700 4:12kV G53 & G56	1,118,812
142	Spare TR40MVA (2-Wind) Elwd P1	1,068,984
143	McHenry Security Technology	1,050,634
144	86790 : FOX LAKE IL59 & GRAND	1,044,866
145	Spare TR40MVA (2-Wind) Elwd P2	1,010,998
146	Spare TR 40MVA (2-Wind) Silv L	1,008,143
147	Other Projects - 2	(c) 207,893,021
148	General Plant
149	UPS A1/B1 Replacement	6,783,371
150	2020 REACTS STA18-TSS60 DFR	6,527,864
151	2019 REACTS TSS157-DCK15 BBF	6,236,563
152	Sugar Grove Trans Lines	6,139,660
153	NORTH VO TSS103 LISLE	6,014,654
154	REACTS 1C224302 TSS30-TSS30-03	5,428,572
155	Ucomm Fibers Svcs CED HW	4,527,898
156	REACTS Schmb E2016-W7415 DFR	4,237,005
157	Maywood Lab expansion	3,853,412
158	2020 REACTS TSS60-TSS60 7 DFR	3,578,377
159	2020 REACTS TSS193-TSS193 DFR	3,360,405
160	2021 REACTS DF-STA13-STA13-03	3,277,422
161	2021 REACTSDF-STA13_2STA13_2 1	3,208,818
162	2021 REACTS DF-STA13-STA13_2-1	3,141,264
163	Supply Automation Project	3,031,362
164	2021 REACTS DF-STA13-STA13-01	2,695,607
165	Long Term Performance Plan - 1	2,574,322
166	Long Term Performance Plan - 2	2,496,120
167	Long Term Performance Plan - 3	2,439,658
168	Long Term Performance Plan - 4	2,401,723
169	Long Term Performance Plan - 5	2,328,236
170	CHICAGO VO TSS150 CALUMET	2,323,780
171	Long Term Performance Plan - 6	2,289,454
172	REACTS R6511 DF TSS165 LINK 01	2,214,761
173	REACTS1C224303 TDC714-TDC714-2	2,197,533
174	DOE Energize	2,171,055
175	Libertyville Training Cntr Cap	2,164,670
176	Long Term Performance Plan - 7	2,154,675
177	Long Term Performance Plan - 8	2,145,482
178	REACTS 1C224303TDC714-TDC714-1	2,092,481
179	2020 REACTS TSS48-TSS48 DFR	2,060,918
180	2019 REACTS TSS945-TSS70 BBF	2,017,730
181	Siemens Controller BMG	2,007,378
182	WEST VO TSS75 CRYSTAL LAKE	1,793,265
183	Long Term Performance Plan - 9	1,709,513
184	2020 REACTS TDC447 to TSS73	1,670,719
185	2019 REACTS TDC294-TSS154 BBF	1,655,660
186	CHICAGO VO TSS54 Clybourn	1,585,865
187	ComEd/PECO CC&B Impl HW	1,555,469
188	Long Term Performance Plan - 10	1,529,203
189	CHICAGO VO STA13-3 Crawford	1,448,056
190	Chicago North EVCS 2023	1,444,853
191	Libertyville HQ HVAC Replcemnt	1,442,242
192	ADMS Task Force - HW	1,440,862
193	2020 REACnTS TDC206	1,413,368
194	REACTS AF-TSS139-TSS139-01.02	1,404,926
195	ATO Monitoring- Chicago	1,394,603
196	2020 REACTS BF-TSS137-SS895	1,390,707
197	2021 REACTS BF-TDC517-TDC531	1,348,357
198	REACTS1C224303 TDC714-TDC714-4	1,338,551
199	2020 REACTS LOC1-LOC2PA	1,286,763
200	2020 REACTS TSS73 to TSS179	1,278,962
201	2020 REACTS TSS60-TDC461-2 DFR	1,215,060
202	Libertyville Ceiling & Lightng	1,211,222
203	Long Term Performance Plan - 11	1,194,545
204	2021 REACTS BF-TSS118-SS875	1,183,012
205	2021 REACTS DF-STA13_2-TSS63-1	1,180,645
206	REACTS 1C224302 STA13-TSS30-01	1,164,160
207	2019 REACTS STA22-STA16 BBF	1,162,471
208	Private LTE Cores & Initia HW	1,135,892
209	2021 REACTS DF-STA13-STA13_2-2	1,055,257
210	Project Post - ESS E 535 - 2	1,042,119
211	2021 REACTS DF-STA13-STA13-07	1,014,858
212	Other Projects - 3	(d) 79,568,540
43	Total	1,395,544,738

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: ConstructionWorkInProgress


There are 54 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

(b) Concept: ConstructionWorkInProgress


There are 294 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.


There are 2,147 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

(d) Concept: ConstructionWorkInProgress


There are 588 projects with a balance of under $1 million that have been grouped under the "Other Projects" caption.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ACCUMULATED PROVISION FOR DEPRECIATION OF ELECTRIC UTILITY PLANT (Account 108)
Explain in a footnote any important adjustments during year. Explain in a footnote any difference between the amount for book cost of plant retired, Line 12, column (c), and that reported for electric plant in service, page 204, column (d), excluding retirements of non-depreciable property. The provisions of Account 108 in the Uniform System of Accounts require that retirements of depreciable plant be recorded when such plant is removed from service. If the respondent has a significant amount of plant retired at year end which has not been recorded and/or classified to the various reserve functional classifications, make preliminary closing entries to tentatively functionalize the book cost of the plant retired. In addition, include all costs included in retirement work in progress at year end in the appropriate functional classifications. Show separately interest credits under a sinking fund or similar method of depreciation accounting.
Line No.	Item (a)	Total (c + d + e) (b)	Electric Plant in Service (c)	Electric Plant Held for Future Use (d)	Electric Plant Leased To Others (e)
Section A. Balances and Changes During Year
1	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance Beginning of Year	10,111,200,105	10,111,200,105
2	Depreciation Provisions for Year, Charged to
3	DepreciationExpenseExcludingAdjustments (403) Depreciation Expense	1,006,052,806	1,006,052,806
4	DepreciationExpenseForAssetRetirementCosts (403.1) Depreciation Expense for Asset Retirement Costs	1,858,923	1,858,923
5	ExpensesOfElectricPlantLeasedToOthers (413) Exp. of Elec. Plt. Leas. to Others
6	TransportationExpensesClearing Transportation Expenses-Clearing	28,804,787	28,804,787
7	OtherClearingAccounts Other Clearing Accounts
8	OtherAccounts Other Accounts (Specify, details in footnote):
9.1	Other Accounts (Specify, details in footnote):	3,796,054	(a) 3,796,054
10	DepreciationProvision TOTAL Deprec. Prov for Year (Enter Total of lines 3 thru 9)	1,032,920,462	1,032,920,462
11	Net Charges for Plant Retired:
12	BookCostOfRetiredPlant Book Cost of Plant Retired	303,544,568	(b) 303,544,568
13	CostOfRemovalOfPlant Cost of Removal	187,215,953	187,215,953
14	SalvageValueOfRetiredPlant Salvage (Credit)	9,757,100	9,757,100
15	NetChargesForRetiredPlant TOTAL Net Chrgs. for Plant Ret. (Enter Total of lines 12 thru 14)	481,003,421	481,003,421
16	OtherAdjustmentsToAccumulatedDepreciation Other Debit or Cr. Items (Describe, details in footnote):
17.1	Other Debit or Cr. Items (Describe, details in footnote):	739,404	(c) 739,404
18	BookCostOfAssetRetirementCosts Book Cost or Asset Retirement Costs Retired	514,630	514,630
19	AccumulatedProvisionForDepreciationOfElectricUtilityPlant Balance End of Year (Enter Totals of lines 1, 10, 15, 16, and 18)	10,663,341,920	10,663,341,920
Section B. Balances at End of Year According to Functional Classification
20	AccumulatedDepreciationSteamProduction Steam Production
21	AccumulatedDepreciationNuclearProduction Nuclear Production
22	AccumulatedDepreciationHydraulicProductionConventional Hydraulic Production-Conventional
23	AccumulatedDepreciationHydraulicProductionPumpedStorage Hydraulic Production-Pumped Storage
24	AccumulatedDepreciationOtherProduction Other Production
25	AccumulatedDepreciationTransmission Transmission	1,737,175,257	1,737,175,257
26	AccumulatedDepreciationDistribution Distribution	7,530,867,345	7,530,867,345
27	AccumulatedDepreciationRegionalTransmissionAndMarketOperation Regional Transmission and Market Operation
28	AccumulatedDepreciationGeneral General	1,395,299,318	(d) 1,395,299,318
29	AccumulatedProvisionForDepreciationOfElectricUtilityPlant TOTAL (Enter Total of lines 20 thru 28)	10,663,341,920	10,663,341,920

FOOTNOTE DATA

(a) Concept: OtherAccounts



Accumulated Depreciation on asset retirement costs charged primarily to Account 182.3	$	(3,796,054)

(b) Concept: BookCostOfRetiredPlant


Retirements per Page 219 for Account 108	$	303,544,568
Retirements per Page 204 for Plant in Service	348,187,154
Difference	$	44,642,586

Details of Difference:
Retirement of Asset Retirement Costs for FIN 47	$	514,630
Retirement of Leasehold improvements charged to Account 111 - Accumulated Provisions for Amortization	5,066,464
Retirement of Software charged to Account 111	39,061,492
Total	$	44,642,586


Adjustments to Account 108 - Accumulated Provision for Depreciation - for revisions recorded to the Asset Retirement Obligations and ARO Regulatory Assets	$	756,864

Adjustments to Account 108 - Accumulated Provision for Depreciation - for transfers related to the refunctionalization of assets and miscellaneous expense adjustments	(17,460)

Total	$	739,404

(d) Concept: AccumulatedDepreciationGeneral


The amount of accumulated depreciation associated with Account 397 (Communication Equipment) as of December 31, 2023 is $862,664,375.07 - 28.56% of such amount is directly assignable to the Transmission function, and 71.44% of such amount is directly assignable to the Distribution function

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

INVESTMENTS IN SUBSIDIARY COMPANIES (Account 123.1)
Report below investments in Account 123.1, Investments in Subsidiary Companies. Provide a subheading for each company and list thereunder the information called for below. Sub-TOTAL by company and give a TOTAL in columns (e), (f), (g) and (h). (a) Investment in Securities - List and describe each security owned. For bonds give also principal amount, date of issue, maturity, and interest rate. (b) Investment Advances - Report separately the amounts of loans or investment advances which are subject to repayment, but which are not subject to current settlement. With respect to each advance show whether the advance is a note or open account. List each note giving date of issuance, maturity date, and specifying whether note is a renewal. Report separately the equity in undistributed subsidiary earnings since acquisition. The TOTAL in column (e) should equal the amount entered for Account 418.1. For any securities, notes, or accounts that were pledged designate such securities, notes, or accounts in a footnote, and state the name of pledgee and purpose of the pledge. If Commission approval was required for any advance made or security acquired, designate such fact in a footnote and give name of Commission, date of authorization, and case or docket number. Report column (f) interest and dividend revenues from investments, including such revenues from securities disposed of during the year. In column (h) report for each investment disposed of during the year, the gain or loss represented by the difference between cost of the investment (or the other amount at which carried in the books of account if different from cost) and the selling price thereof, not including interest adjustment includible in column (f). Report on Line 42, column (a) the TOTAL cost of Account 123.1.
Line No.	DescriptionOfInvestmentsInSubsidiaryCompanies Description of Investment (a)	DateOfAcquisitionInvestmentsInSubsidiaryCompanies Date Acquired (b)	DateOfMaturityInvestmentsInSubsidiaryCompanies Date of Maturity (c)	InvestmentInSubsidiaryCompanies Amount of Investment at Beginning of Year (d)	EquityInEarningsOfSubsidiaryCompanies Equity in Subsidiary Earnings of Year (e)	InterestAndDividendRevenueFromInvestments Revenues for Year (f)	InvestmentInSubsidiaryCompanies Amount of Investment at End of Year (g)	InvestmentGainLossOnDisplosal Gain or Loss from Investment Disposed of (h)
1	Commonwealth Edison Company of Indiana, Inc.	12/31/1962
2	Common Stock, no par value (III. C.C. Docket Number 46967)			6,189,528			6,189,528
3	Other Capital Stock Transactions - Net			34,161,813			34,161,813
4	Undistributed Earnings			50,194,838	5,124,608	356,735	55,676,181
5	Subtotal			90,546,179	5,124,608	356,735	96,027,522
6	ComEd Financing III
7	Common Securities (III. C. C. Docket Number 02-0562)			6,186,000			6,186,000
8	Undistributed Earnings			115,661	392,811	392,811	115,661
9	Subtotal			6,301,661	392,811	392,811	6,301,661
10	EdiSun, LLC
11	Ownership Interest			61,592			61,592
12	RITELine Illinois, LLC
13	Ownership Interest			20,537			20,537
42	Total Cost of Account 123.1 $ 12,375,528		Total	96,806,785	5,517,419	36,076	102,288,128

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

MATERIALS AND SUPPLIES
For Account 154, report the amount of plant materials and operating supplies under the primary functional classifications as indicated in column (a); estimates of amounts by function are acceptable. In column (d), designate the department or departments which use the class of material. Give an explanation of important inventory adjustments during the year (in a footnote) showing general classes of material and supplies and the various accounts (operating expenses, clearing accounts, plant, etc.) affected debited or credited. Show separately debit or credits to stores expense clearing, if applicable.
Line No.	Account (a)	Balance Beginning of Year (b)	Balance End of Year (c)	Department or Departments which Use Material (d)
1	Fuel Stock (Account 151)
2	Fuel Stock Expenses Undistributed (Account 152)
3	Residuals and Extracted Products (Account 153)
4	Plant Materials and Operating Supplies (Account 154)
5	Assigned to - Construction (Estimated)	180,001,069	(a) 268,199,577
6	Assigned to - Operations and Maintenance
7	Production Plant (Estimated)
8	Transmission Plant (Estimated)	6,123,521	4,642,775	Transmission
9	Distribution Plant (Estimated)	8,890,161	12,718,935	Distribution
10	Regional Transmission and Market Operation Plant (Estimated)
11	Assigned to - Other (provide details in footnote)
12	TOTAL Account 154 (Enter Total of lines 5 thru 11)	195,014,751	285,561,287
13	Merchandise (Account 155)
14	Other Materials and Supplies (Account 156)
15	Nuclear Materials Held for Sale (Account 157) (Not applic to Gas Util)
16	Stores Expense Undistributed (Account 163)
17
18
19
20	TOTAL Materials and Supplies	195,014,751	285,561,287

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: PlantMaterialsAndOperatingSuppliesConstruction


Assigned to - Construction (Estimated)
Transmission Plant (Estimated)	$	57,496,141
Distribution Plant (Estimated)	210,703,436
Assigned to - Construction (Estimated)	$	268,199,577

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	SO2 Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

Allowances (Accounts 158.1 and 158.2)
Report below the particulars (details) called for concerning allowances. Report all acquisitions of allowances at cost. Report allowances in accordance with a weighted average cost allocation method and other accounting as prescribed by General Instruction No. 21 in the Uniform System of Accounts. Report the allowances transactions by the period they are first eligible for use: the current year’s allowances in columns (b)-(c), allowances for the three succeeding years in columns (d)-(i), starting with the following year, and allowances for the remaining succeeding years in columns (j)-(k). Report on Line 4 the Environmental Protection Agency (EPA) issued allowances. Report withheld portions Lines 36-40. Report on Line 5 allowances returned by the EPA. Report on Line 39 the EPA’s sales of the withheld allowances. Report on Lines 43-46 the net sales proceeds and gains/losses resulting from the EPA’s sale or auction of the withheld allowances. Report on Lines 8-14 the names of vendors/transferors of allowances acquired and identify associated companies (See "associated company" under "Definitions" in the Uniform System of Accounts). Report on Lines 22 - 27 the name of purchasers/ transferees of allowances disposed of and identify associated companies. Report the net costs and benefits of hedging transactions on a separate line under purchases/transfers and sales/transfers. Report on Lines 32-35 and 43-46 the net sales proceeds and gains or losses from allowance sales.
		Current Year		Year One		Year Two		Year Three		Future Years		Totals
Line No.	NOx Allowances Inventory (Account 158.1) (a)	No. (b)	Amt. (c)	No. (d)	Amt. (e)	No. (f)	Amt. (g)	No. (h)	Amt. (i)	No. (j)	Amt. (k)	No. (l)	Amt. (m)
1	Balance-Beginning of Year
2
3	Acquired During Year:
4	Issued (Less Withheld Allow)
5	Returned by EPA
6
7
8
9
10
11
12
13
14
15	Total
16
17	Relinquished During Year:
18	Charges to Account 509
19	Other:
20	Allowances Used
20.1	Allowances Used
21	Cost of Sales/Transfers:
22
23
24
25
26
27
28	Total
29	Balance-End of Year
30
31	Sales:
32	Net Sales Proceeds(Assoc. Co.)
33	Net Sales Proceeds (Other)
34	Gains
35	Losses
	Allowances Withheld (Acct 158.2)
36	Balance-Beginning of Year
37	Add: Withheld by EPA
38	Deduct: Returned by EPA
39	Cost of Sales
40	Balance-End of Year
41
42	Sales
43	Net Sales Proceeds (Assoc. Co.)
44	Net Sales Proceeds (Other)
45	Gains
46	Losses

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

EXTRAORDINARY PROPERTY LOSSES (Account 182.1)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfExtraordinaryPropertyLoss Description of Extraordinary Loss [Include in the description the date of Commission Authorization to use Acc 182.1 and period of amortization (mo, yr to mo, yr).] (a)	ExtraordinaryPropertyLossesNotYetRecognized Total Amount of Loss (b)	ExtraordinaryPropertyLossesRecognized Losses Recognized During Year (c)	ExtraordinaryPropertyLossesWrittenOffAccountCharged Account Charged (d)	ExtraordinaryPropertyLossesWrittenOff Amount (e)	ExtraordinaryPropertyLosses Balance at End of Year (f)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
20	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

UNRECOVERED PLANT AND REGULATORY STUDY COSTS (182.2)
				WRITTEN OFF DURING YEAR
Line No.	DescriptionOfUnrecoveredPlantAndRegulatoryStudyCosts Description of Unrecovered Plant and Regulatory Study Costs [Include in the description of costs, the date of COmmission Authorization to use Acc 182.2 and period of amortization (mo, yr to mo, yr)] (a)	UnrecoveredPlantAndRegulatoryStudyCostsNotYetRecognized Total Amount of Charges (b)	UnrecoveredPlantAndRegulatoryStudyCostsRecognized Costs Recognized During Year (c)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOffAccountCharged Account Charged (d)	UnrecoveredPlantAndRegulatoryStudyCostsWrittenOff Amount (e)	UnrecoveredPlantAndRegulatoryStudyCosts Balance at End of Year (f)
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

Transmission Service and Generation Interconnection Study Costs
Report the particulars (details) called for concerning the costs incurred and the reimbursements received for performing transmission service and generator interconnection studies. List each study separately. In column (a) provide the name of the study. In column (b) report the cost incurred to perform the study at the end of period. In column (c) report the account charged with the cost of the study. In column (d) report the amounts received for reimbursement of the study costs at end of period. In column (e) report the account credited with the reimbursement received for performing the study.
Line No.	DescriptionOfStudyPerformed Description (a)	StudyCostsIncurred Costs Incurred During Period (b)	StudyCostsAccountCharged Account Charged (c)	StudyCostsReimbursements Reimbursements Received During the Period (d)	StudyCostsAccountReimbursed Account Credited With Reimbursement (e)
1	Transmission Studies
2	PJM AD1-031 Kewanee-ED Edwards	31	408.1	751	456
3	PJM AD1-031 Kewanee-ED Edwards	91	926
4	PJM AD1-031 Kewanee-ED Edwards	423	561.6
5	PJM AD1-031 Kewanee-ED Edwards	206	921
6	PJM AD2-047 Davis Creek 138kV	126	408.1	1,846	456
7	PJM AD2-047 Davis Creek 138kV	370	926
8	PJM AD2-047 Davis Creek 138kV	1,630	561.6
9	PJM AD2-047 Davis Creek 138kV	359	921
10	PJM AD2-066 Mazon-Crescent Rid	32	408.1	539	456
11	PJM AD2-066 Mazon-Crescent Rid	102	926
12	PJM AD2-066 Mazon-Crescent Rid	733	561.6
13	PJM AD2-066 Mazon-Crescent Rid	20	570
14	PJM AD2-066 Mazon-Crescent Rid	80	921
15	PJM AE1-070 Elwood 345 kV Faci	103	408.1	2,923	456
16	PJM AE1-070 Elwood 345 kV Faci	299	926
17	PJM AE1-070 Elwood 345 kV Faci	1,804	561.6
18	PJM AE1-070 Elwood 345 kV Faci	717	921
19	Powerton-Nevada FS AE1-163	244	408.1	19,325	456
20	Powerton-Nevada FS AE1-163	848	926
21	Powerton-Nevada FS AE1-163	15,473	561.6
22	Powerton-Nevada FS AE1-163	2,760	921
23	AE1-193 PJM Facilities Study-K	134	408.1	3,855	456
24	AE1-193 PJM Facilities Study-K	394	926
25	AE1-193 PJM Facilities Study-K	2,379	561.6
26	AE1-193 PJM Facilities Study-K	948	921
27	AE1-194 PJM Facilities Study-K	92	408.1	2,853	456
28	AE1-194 PJM Facilities Study-K	274	926
29	AE1-194 PJM Facilities Study-K	1,817	561.6
30	AE1-194 PJM Facilities Study-K	670	921
31	AE1-195 PJM Facilities Study	92	408.1	2,853	456
32	AE1-195 PJM Facilities Study	274	926
33	AE1-195 PJM Facilities Study	1,817	561.6
34	AE1-195 PJM Facilities Study	670	921
35	AE1-198 PJM Facilities Study	372	561.6		456
20	Total	34,134		33,867
21	Generation Studies
22	Twombly Facility Study	927	561.7	1,004	456
23	Twombly Facility Study	77	921
24	PJM AD1-039 Kendall-Tazewell	10	408.1	272	456
25	PJM AD1-039 Kendall-Tazewell	163	561.7
26	PJM AD1-039 Kendall-Tazewell	30	926
27	PJM AD1-039 Kendall-Tazewell	69	921
28	AD1-098 Dixon to McFirr PJM	1,889	408.1	98,384	456
29	AD1-098 Dixon to McFirr PJM	73,610	561.7
30	AD1-098 Dixon to McFirr PJM	5,868	926
31	AD1-098 Dixon to McFirr PJM	17,017	921
32	100 Facility Study	23	408.1	620	456
33	100 Facility Study	371	561.7
34	100 Facility Study	68	926
35	100 Facility Study	158	921
36	102 Facility Study	27	408.1	702	456
37	102 Facility Study	422	561.7
38	102 Facility Study	75	926
39	102 Facility Study	178	921
40	Shady Oaks Facility Study	683	408.1	45,365	456
41	Shady Oaks Facility Study	35,251	561.7
42	Shady Oaks Facility Study	2,164	926
43	Shady Oaks Facility Study	7,267	921
44	Rock Falls Garden Facility Study	4	408.1	92	456
45	Rock Falls Garden Facility Study	52	561.7
46	Rock Falls Garden Facility Study	11	926
47	Rock Falls Garden Facility Study	25	921
48	AE1-114 PJM Facilities Study	522	408.1	13,069	456
49	AE1-114 PJM Facilities Study	7,784	561.7
50	AE1-114 PJM Facilities Study	1,392	926
51	AE1-114 PJM Facilities Study	3,371	921
52	AE1-166 PJM Facilities Study	235	408.1	7,629	456
53	AE1-166 PJM Facilities Study	4,918	561.7
54	AE1-166 PJM Facilities Study	699	926
55	AE1-166 PJM Facilities Study	1,777	921
56	AE1-205 PJM Facilities Study	346	408.1	12,006	456
57	AE1-205 PJM Facilities Study	7,919	561.7
58	AE1-205 PJM Facilities Study	1,048	926
59	AE1-205 PJM Facilities Study	2,693	921
60	AE1-252 PJM Facilities Study	93	408.1	2,857	456
61	AE1-252 PJM Facilities Study	1,819	561.7
62	AE1-252 PJM Facilities Study	274	926
63	AE1-252 PJM Facilities Study	671	921
64	PJM AE2-152 Loretto-WiltonBrai	485	408.1	22,107	456
65	PJM AE2-152 Loretto-WiltonBrai	17,789	561.7
66	PJM AE2-152 Loretto-WiltonBrai	781	926
67	PJM AE2-152 Loretto-WiltonBrai	661	570
68	PJM AE2-152 Loretto-WiltonBrai	3,087	921
69	PJM AE2-173: MCLEAN 345 KV	1,415	408.1	59,343	456
70	PJM AE2-173: MCLEAN 345 KV	42,600	561.7
71	PJM AE2-173: MCLEAN 345 KV	3,901	926
72	PJM AE2-173: MCLEAN 345 KV	11,427	921
73	PJM AE2-341 Facility Study	87	408.1	8,566	456
74	PJM AE2-341 Facility Study	7,081	561.7
75	PJM AE2-341 Facility Study	257	926
76	PJM AE2-341 Facility Study	1,141	921
77	Nelson Facility Study - Elec Junction	26	408.1	2,197	456
78	Nelson Facility Study - Elec Junction	1,812	561.7
79	Nelson Facility Study - Elec Junction	72	926
80	Nelson Facility Study - Elec Junction	287	921
81	PJM AF1-030 Facility Study	150	408.1	8,375	456
82	PJM AF1-030 Facility Study	6,293	561.7
83	PJM AF1-030 Facility Study	483	926
84	PJM AF1-030 Facility Study	1,449	921
85	AF-2041 Nelson-Elec Junc 345kV	10	408.1	286	456
86	AF-2041 Nelson-Elec Junc 345kV	182	561.7
87	AF-2041 Nelson-Elec Junc 345kV	27	926
88	AF-2041 Nelson-Elec Junc 345kV	67	921
89	PJM AFS-128 Crescent Ridge-Cor	72	408.1	4,066	456
90	PJM AFS-128 Crescent Ridge-Cor	3,129	561.7
91	PJM AFS-128 Crescent Ridge-Cor	209	926
92	PJM AFS-128 Crescent Ridge-Cor	656	921
93	AF2-199 Nelson-Elec Junc 345kV	9	408.1	285	456
94	AF2-199 Nelson-Elec Junc 345kV	182	561.7
95	AF2-199 Nelson-Elec Junc 345kV	27	926
96	AF2-199 Nelson-Elec Junc 345kV	67	921
97	AF2-349 Garden Prairie 345 kV	150	408.1	15,117	456
98	AF2-349 Garden Prairie 345 kV	11,874	561.7
99	AF2-349 Garden Prairie 345 kV	1,003	926
100	AF2-349 Garden Prairie 345 kV	2,218	921
101	PJM TFAJ1464	613	408.1	40,523	456
102	PJM TFAJ1464	31,589	561.7
103	PJM TFAJ1464	2,015	926
104	PJM TFAJ1464	6,306	921
105	Mole Creek Facility Study	89	408.1	7,897	456
106	Mole Creek Facility Study	6,370	561.7
107	Mole Creek Facility Study	302	926
108	Mole Creek Facility Study	1,136	921
109	UPRATE AD2-194 @TSS 929	944	408.1	42,581	456
110	UPRATE AD2-194 @TSS 929	31,532	561.7
111	UPRATE AD2-194 @TSS 929	2,316	926
112	UPRATE AD2-194 @TSS 929	7,789	921
113	JM MISO J955 FACILITIES STUDY	2,532	408.1	85,260	456
114	JM MISO J955 FACILITIES STUDY	61,048	561.7
115	JM MISO J955 FACILITIES STUDY	5,191	926
116	JM MISO J955 FACILITIES STUDY	16,489	921
117	ISO J1377 - PJM Facilities	339	408.1	6,383	456
118	ISO J1377 - PJM Facilities	3,808	561.7
119	ISO J1377 - PJM Facilities	675	926
120	ISO J1377 - PJM Facilities	1,561	921
121	AC1-171 Expense			1	456
122	Normandy-Kewanee 138kV U4-027			158	456
39	Total	484,386		483,719
40	Grand Total	518,520		517,586

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

OTHER REGULATORY ASSETS (Account 182.3)
Report below the particulars (details) called for concerning other regulatory assets, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 182.3 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Assets being amortized, show period of amortization.
				CREDITS
Line No.	DescriptionAndPurposeOfOtherRegulatoryAssets Description and Purpose of Other Regulatory Assets (a)	OtherRegulatoryAssets Balance at Beginning of Current Quarter/Year (b)	IncreaseDecreaseInOtherRegulatoryAssets Debits (c)	OtherRegulatoryAssetsWrittenOffAccountCharged Written off During Quarter/Year Account Charged (d)	OtherRegulatoryAssetsWrittenOffRecovered Written off During the Period Amount (e)	OtherRegulatoryAssets Balance at end of Current Quarter/Year (f)
1	(a) Capitalized Employee Incentive Payments	5,384,614		407.3	287,485	5,097,129
2	Deferred Asset Retirement Obligation Costs	98,582,971	7,608,909	403.1	1,725,375	104,466,505
3	Cash Flow Swap Settlement Costs	5,238,366		427	519,507	4,718,859
4	MGP Remediation Costs	293,207,717	35,238,367	407.3	42,238,955	286,207,129
5	Renewable Energy Swaps	84,619,628	49,013,174	242 / 253		133,632,802
6	AMI Meter Accelerated Depreciation	47,654,975		407.3	19,582,450	28,072,525
7	Carbon Mitigation Credit	843,029,431	679,334,695	557	849,821,106	672,543,020
8	Rate Case	2,160,188	5,128,081	407.3 / Revenue	2,067,098	5,221,171
9	Uncollectible Accounts Expense - Under Recovery	46,912,297	40,664,866	407.4	9,122,925	78,454,238
10	Distribution Service Costs	406,058,390	531,266,870	407.3 / Revenue	50,743,686	886,581,574
11	Energy Efficiency Costs	1,433,937,303	453,019,091	407.3 / Revenue	195,519,578	1,691,436,816
12	Capital Lease Excess Depreciation	1,658,561	151,224	589		1,809,785
13	Purchased Receivables Program - Under Recovery	10,726,591	3,650,253	407.3		14,376,844
14	Purchased Electricity - Under Recovery	37,823,561	26,492,153	555	48,903,388	15,412,326
15	Distributed Generation Rebate Costs	98,485,989	19,211,025	407.3 / Revenue	9,264,200	108,432,814
16	Transmission Costs - Under Recovery	8,448,386	6,355,892	456.1		14,804,278
17	Parallel Operation of Retail Customer Generating Facilities Community Supply	358,059	5,711,099	555	3,196,304	2,872,854
18	Coal to Solar			557
19	Zero Emissions Program		59,681,968	557	1,570,047	58,111,921
20	Deferred Income Taxes		284,311,635	282, 283, 410, 411		284,311,635
44	TOTAL	3,424,287,027	2,206,839,302		1,234,562,104	4,396,564,225

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryAssets

Line Item

Rate Order Docket Number Or Recovery Mechanism

Amortization Period

Capitalized Employee Incentive Payments

ICC Docket 01-0423

3/31/2003 - 7/31/2043

Deferred Asset Retirement Obligation Costs

Distribution & Transmission Formula Rates

Over the life of related Assets

Cash Flow Swap Settlement Costs

Distribution & Transmission Formula Rates

3/15/2002 - 1/31/2033

MGP Remediation Costs

ICC Docket 05-0597

1/1/2007 - 12/31/2025

Renewable Energy Swaps

ICC Docket No. 09-0373

6/1/2012 - 5/1/2032

AMI Meter Accelerated Depreciation

ICC Docket 12-0298

1/1/2014-12/31/2028

Carbon Mitigation Credit

CEJA

BA: 12 months from June 2023

and

MR: 4 months from period end

Rate Case

CEJA

1/1/2024-12/31/2027

Uncollectible Accounts Expense

ICC Docket No. 09-0433 & 20-0309

12 months from each June

Distribution Service Costs

EIMA & FEJA
SB2408 - Clean Energy Law - Distribution Formula Transition for year 2022 & 2023

3-5 years

Energy Efficiency Costs

FEJA

Over the measurable life of efficiency measures

Capital Lease Excess Depreciation

Distribution Formula Rate

2039 - 2053

Purchased Receivables Program - Under Recovery

ICC Docket 10-0138

1/1/2011 - 12/31/2020

Purchased Electricity - Under Recovery

ICC Docket No. 05-0159 & 18-1824

4 months from period end

Distributed Generation Rebate Costs

FEJA

15 years

Transmission Costs - Under Recovery

FERC Docket ER07-583

12 months from each June

Parallel Operation of Retail Customer Generating Facilities Community Supply

ICC Docket 22-0305

Not determined yet

Zero Emissions Program

FEJA

9 months from each September

Deferred Income Taxes

ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/19

Over the life of related assets

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

MISCELLANEOUS DEFFERED DEBITS (Account 186)
Report below the particulars (details) called for concerning miscellaneous deferred debits. For any deferred debit being amortized, show period of amortization in column (a) Minor item (1% of the Balance at End of Year for Account 186 or amounts less than $100,000, whichever is less) may be grouped by classes.
				CREDITS
Line No.	Description of Miscellaneous Deferred Debits (a)	Balance at Beginning of Year (b)	Debits (c)	Credits Account Charged (d)	Credits Amount (e)	Balance at End of Year (f)
1	Accumulated under/Over recoveries -local government
2	compliance causes	280,674	1,851,431	(a) Various	1,733,985	398,120
3	Vacation pay and payroll taxes pending proper accounting
4	distribution	24,302,455	335,087,631	242	333,607,546	25,782,540
5	Long-Term contracting services	604,063	40,529	517, 528	355,920	288,672
6	Cook County Forest Preserve District License Fees to be
7	amortized through 2027 - 1	3,860,550	4,974,786	589	5,492,975	3,342,361
8	Pension Asset	1,206,194,555	23,812,127	184, 926	12,825,430	1,217,181,252
9	Long Term receivable from Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) (SFAS 143, Regulatory Liability offset)	2,659,759,104	668,146,758	254.1	373,493,682	2,954,412,180
10	Long Term receivable from the MBA Plan	2,131,997	65,023,044	143, 253	64,420,543	2,734,498
11	Credit facilities - ICC fees and other issuance costs to be
12	amortized through 2027 - 2	962,105		131, 141	658,507	303,598
13	ICC Financing Authority Fees	3,221,803	4,800,000	143, 181	2,340,000	5,681,803
14	Insurance recoveries related to third party claims	6,272,776	1,983,070	925	1,025,000	7,230,846
15	Estimated Illinois Distribution Tax Refund	6,567,897	4,660,257	143, 236, 408.1	7,166,937	4,061,217
16	Long Term Restricted Cash	116,893,579	133,291,678	134	76,637,041	173,548,216
17	Long-Term Receivable Related to the FERC 494 Refund	10,557,277		254	5,278,637	5,278,640
18	Microgrid Prepayment	446,414		535	82,175	364,239
19	Adjustable Block REC Prepayments	367,819,028	211,674,764	165	4,219,914	575,273,878
20	Long-term portion of receivables from deferred payment
21	agreements	1,381,006	432,275	142	423,536	1,389,745
22	Rochelle Franchise Fees to be amortized through 2070	1,410,000		253	30,000	1,380,000
23	Illinois Solar for All Program REC Prepayment	7,359,346	7,998,673	165	391,237	14,966,782
24	Meter/Equipment Purchases	33,415	2,222	517	35,637
25	REACTS Fiber Program	182,942		107	43,605	139,337
26	Skydio Cloud 3yr Subscription Purchase	187,425		514	93,713	93,712
27	I&M Canal Fees to be amortized through June 2033		446,967	931	16,867	430,100
28	Maywood Outdoor Lab Program		816,074			816,074
29	Minor Items	2,652,752	466,287,275	(b) Various	466,798,817	2,141,210
47	Miscellaneous Work in Progress	249,008				228,940
48	Deferred Regulatory Comm. Expenses (See pages 350 - 351)
49	TOTAL	4,423,330,171				4,997,467,960

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged


Accumulated under/over recoveries are offset in Accounts 107000, 108030, 535250, 615000, 143300,410090, 131000, 232100, and 503000.

(b) Concept: DecreaseInMiscellaneousDeferredExpenseAccountCharged


Minor items are offset in Accounts 107000, 131100, 182890, 184100, 184200, 228200, 232000, 232900, 241000, 242000, 242200, 242300, 514000, 514062, 517010, 535000 and 535160.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ACCUMULATED DEFERRED INCOME TAXES (Account 190)
Report the information called for below concerning the respondent’s accounting for deferred income taxes. At Other (Specify), include deferrals relating to other income and deductions.
Line No.	DescriptionOfAccumulatedDeferredIncomeTax Description and Location (a)	AccumulatedDeferredIncomeTaxes Balance at Beginning of Year (b)	AccumulatedDeferredIncomeTaxes Balance at End of Year (c)
1	Electric
2		(a) 268,238,892	1,006,863,343
7	Other
8	TOTAL Electric (Enter Total of lines 2 thru 7)	268,238,892	(b) 1,006,863,343
9	Gas
15	Other
16	TOTAL Gas (Enter Total of lines 10 thru 15)
17.1	Other (Specify)
17	Other (Specify)
18	TOTAL (Acct 190) (Total of lines 8, 16 and 17)	268,238,892	1,006,863,343

Notes

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxes


Account 190 Federal Inc. Activity:
410 Debits	$	52,429,002
411 Credits	177,730,923
Net Debit/(Credits)	$	(125,301,921)

Account 190 State Inc. Activity:
410 Debits	$	538,996
411 Credits	14,301,851
Net Debit/(Credits)	$	(13,762,855)

Account 190 Activity B/S Only:
Debits	$	599,559,675
Credits	—
Net Adjustments	$	599,559,675

Net Change	$	738,624,451

(b) Concept: AccumulatedDeferredIncomeTaxes


Account 190 Description:
Accrued Benefits	$	2,455,092	$	4,018,069
Accrued Bonuses & Incentives	38,115,349		43,529,546
Accrued Legal	14,226		14,253
Accrued Severance	780,354		1,019,238
Accrued Vacation	9,904,991		10,314,195
Accrued Workers' Compensation	17,692,874		22,654,211
Accrued OPEB	52,482,346		47,474,964
Allowance for Doubtful Accounts	23,718,257		23,640,736
Charitable Contribution Carryforward	1,975,093		—
Corporate Alternative Minimum Tax	—		118,023,568
Deferred Compensation	8,250,079		8,499,188
Deferred Revenue	2,868,752		2,405,758
Environmental Cleanup Costs	431,243		13,150,719
Manufactured Gas Plants	127,777,860		73,091,938
Obsolete Materials	2,250,259		1,809,907
Other - 190	22,051,220		9,892,629
Regulatory Liability	(11,510,534)		620,745,033
State Income Taxes	7,221,187		4,294,062
Unamortized Investment Tax Credit	(38,239,756)		2,285,329
Total	$	268,238,892	$	1,006,863,343

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

CAPITAL STOCKS (Account 201 and 204)
Report below the particulars (details) called for concerning common and preferred stock at end of year, distinguishing separate series of any general class. Show separate totals for common and preferred stock. If information to meet the stock exchange reporting requirement outlined in column (a) is available from the SEC 10-K Report Form filing, a specific reference to report form (i.e., year and company title) may be reported in column (a) provided the fiscal years for both the 10-K report and this report are compatible. Entries in column (b) should represent the number of shares authorized by the articles of incorporation as amended to end of year. Give details concerning shares of any class and series of stock authorized to be issued by a regulatory commission which have not yet been issued. The identification of each class of preferred stock should show the dividend rate and whether the dividends are cumulative or noncumulative. State in a footnote if any capital stock that has been nominally issued is nominally outstanding at end of year. Give particulars (details) in column (a) of any nominally issued capital stock, reacquired stock, or stock in sinking and other funds which is pledged, stating name of pledgee and purpose of pledge.
Line No.	Class and Series of Stock and Name of Stock Series (a)	Number of Shares Authorized by Charter (b)	Par or Stated Value per Share (c)	Call Price at End of Year (d)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Shares (e)	Outstanding per Bal. Sheet (Total amount outstanding without reduction for amounts held by respondent) Amount (f)	Held by Respondent As Reacquired Stock (Acct 217) Shares (g)	Held by Respondent As Reacquired Stock (Acct 217) Cost (h)	Held by Respondent In Sinking and Other Funds Shares (i)	Held by Respondent In Sinking and Other Funds Amount (j)
1	Common Stock (Account 201)
2	(a) Total Common Stock	250,000,000			127,021,399	1,587,297,032
6	Total	250,000,000			127,021,399	1,587,297,032
7	Preferred Stock (Account 204)
8
9
10
11	Total
1	Capital Stock (Accounts 201 and 204) - Data Conversion
2
3
4
5	Total

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: CapitalStockDescription

ComEd had 60,032 and 60,051 warrants outstanding to purchase ComEd common stock at December 31, 2023 and 2022, respectively. The warrants entitle the holders to convert such warrants into common stock of ComEd at a conversion rate of one share of common stock for three warrants. At December 31, 2023 and 2022, 20,011 and 20,017 shares of common stock, respectively, were reserved for the conversion of warrants.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-12-31

Year/Period of Report

End of:

2023

Other Paid-in Capital
1. Report below the balance at the end of the year and the information specified below for the respective other paid-in capital accounts. Provide a subheading for each account and show a total for the account, as well as a total of all accounts for reconciliation with the balance sheet, page 112. Explain changes made in any account during the year and give the accounting entries effecting such change. Donations Received from Stockholders (Account 208) - State amount and briefly explain the origin and purpose of each donation. Reduction in Par or Stated Value of Capital Stock (Account 209) - State amount and briefly explain the capital changes that gave rise to amounts reported under this caption including identification with the class and series of stock to which related. Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210) - Report balance at beginning of year, credits, debits, and balance at end of year with a designation of the nature of each credit and debit identified by the class and series of stock to which related. Miscellaneous Paid-In Capital (Account 211) - Classify amounts included in this account according to captions that, together with brief explanations, disclose the general nature of the transactions that gave rise to the reported amounts.
Line No.	Item (a)	Amount (b)
1	DonationsReceivedFromStockholdersAbstract Donations Received from Stockholders (Account 208)
2	DonationsReceivedFromStockholders Beginning Balance Amount
3.1	IncreasesDecreasesFromSalesOfDonationsReceivedFromStockholders Increases (Decreases) from Sales of Donations Received from Stockholders
4	DonationsReceivedFromStockholders Ending Balance Amount
5	ReductionInParOrStatedValueOfCapitalStockAbstract Reduction in Par or Stated Value of Capital Stock (Account 209)
6	ReductionInParOrStatedValueOfCapitalStock Beginning Balance Amount
7.1	IncreasesDecreasesDueToReductionsInParOrStatedValueOfCapitalStock Increases (Decreases) Due to Reductions in Par or Stated Value of Capital Stock
8	ReductionInParOrStatedValueOfCapitalStock Ending Balance Amount
9	GainOrResaleOrCancellationOfReacquiredCapitalStockAbstract Gain or Resale or Cancellation of Reacquired Capital Stock (Account 210)
10	GainOnResaleOrCancellationOfReacquiredCapitalStock Beginning Balance Amount
11.1	IncreasesDecreasesFromGainOrResaleOrCancellationOfReacquiredCapitalStock Increases (Decreases) from Gain or Resale or Cancellation of Reacquired Capital Stock
12	GainOnResaleOrCancellationOfReacquiredCapitalStock Ending Balance Amount
13	MiscellaneousPaidInCapitalAbstract Miscellaneous Paid-In Capital (Account 211)
14	MiscellaneousPaidInCapital Beginning Balance Amount	4,733,210,990
15.1	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Warrants	(a) 253
15.2	IncreasesDecreasesDueToMiscellaneousPaidInCapital Increases (Decreases) Due to Miscellaneous Paid-In Capital	655,545,330
16	MiscellaneousPaidInCapital Ending Balance Amount	(b) 5,388,756,067
17	OtherPaidInCapitalAbstract Historical Data - Other Paid in Capital
18	OtherPaidInCapitalDetail Beginning Balance Amount
19.1	IncreasesDecreasesInOtherPaidInCapital Increases (Decreases) in Other Paid-In Capital
20	OtherPaidInCapitalDetail Ending Balance Amount
40	OtherPaidInCapital Total	5,388,756,067

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

2023-12-31

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: IncreasesDecreasesDueToMiscellaneousPaidInCapital


These amounts represent the balances related to the following types of Common Stock Purchase Warrants:
	Beginning Balance as of 12/31/2022	2023 YTD Activity	Ending Balance as of 12/31/2023
1971 Warrants	526,006	(195)	525,811
Series B Warrants	227,208	(58)	227,150
Total Warrants	753,214	(253)	752,961

(b) Concept: MiscellaneousPaidInCapital


The ending balance is comprised of $752,961 for Common Stock Purchase Warrants and $5,388,003,106 of other paid in capital. This other paid in capital amount represents the other paid in capital recognized from the indemnification from Exelon Corporation, the Respondent's parent, in related to the like-kind exchange transaction and to support expanded capital programs. See Note 7 - Income Taxes of the Notes to Financial Statements for additional information related to the like-kind exchanges.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

CAPITAL STOCK EXPENSE (Account 214)
Report the balance at end of the year of discount on capital stock for each class and series of capital stock. If any change occurred during the year in the balance in respect to any class or series of stock, attach a statement giving particulars (details) of the change. State the reason for any charge-off of capital stock expense and specify the account charged.
Line No.	NameOfClassAndSeriesOfStock Class and Series of Stock (a)	CapitalStockExpense Balance at End of Year (b)
1	Common Stock	6,942,925
22	TOTAL	6,942,925

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

LONG-TERM DEBT (Account 221, 222, 223 and 224)
Report by Balance Sheet Account the details concerning long-term debt included in Accounts 221, Bonds, 222, Reacquired Bonds, 223, Advances from Associated Companies, and 224, Other Long-Term Debt. For bonds assumed by the respondent, include in column (a) the name of the issuing company as well as a description of the bonds, and in column (b) include the related account number. For Advances from Associated Companies, report separately advances on notes and advances on open accounts. Designate demand notes as such. Include in column (a) names of associated companies from which advances were received, and in column (b) include the related account number. For receivers' certificates, show in column (a) the name of the court and date of court order under which such certificates were issued, and in column (b) include the related account number. In a supplemental statement, give explanatory details for Accounts 223 and 224 of net changes during the year. With respect to long-term advances, show for each company: (a)principal advanced during year (b) interest added to principal amount, and (c) principal repaid during year. Give Commission authorization numbers and dates. If the respondent has pledged any of its long-term debt securities, give particulars (details) in a footnote, including name of the pledgee and purpose of the pledge. If the respondent has any long-term securities that have been nominally issued and are nominally outstanding at end of year, describe such securities in a footnote. If interest expense was incurred during the year on any obligations retired or reacquired before end of year, include such interest expense in column (m). Explain in a footnote any difference between the total of column (m) and the total Account 427, Interest on Long-Term Debt and Account 430, Interest on Debt to Associated Companies. Give details concerning any long-term debt authorized by a regulatory commission but not yet issued.
Line No.	ClassAndSeriesOfObligationCouponRateDescription Class and Series of Obligation, Coupon Rate (For new issue, give commission Authorization numbers and dates) (a)	RelatedAccountNumber Related Account Number (b)	Principal Amount of Debt Issued (c)	LongTermDebtIssuanceExpensePremiumOrDiscount Total Expense, Premium or Discount (d)	LongTermDebtIssuanceExpenses Total Expense (e)	LongTermDebtPremium Total Premium (f)	LongTermDebtDiscount Total Discount (g)	NominalDateOfIssue Nominal Date of Issue (h)	DateOfMaturity Date of Maturity (i)	AmortizationPeriodStartDate AMORTIZATION PERIOD Date From (j)	AmortizationPeriodEndDate AMORTIZATION PERIOD Date To (k)	Outstanding (Total amount outstanding without reduction for amounts held by respondent) (l)	Interest for Year Amount (m)
1	Bonds (Account 221)
2	100, 5.875%	221	350,000,000		3,525,036		1,526,000	01/22/2003	02/01/2033	01/22/2003	02/01/2033	253,600,000	14,899,000
3	103, 5.900%	221	325,000,000		3,488,737		2,044,250	03/06/2006	03/15/2036	03/06/2006	03/15/2036	325,000,000	19,175,000
4	103B, 5.900%	221	300,000,000		1,048,534		12,435,000	03/22/2007	03/15/2036	03/22/2007	03/15/2036	300,000,000	17,700,000
5	107, 6.450%	221	450,000,000		4,468,683		1,359,000	01/16/2008	01/15/2038	01/16/2008	01/15/2038	450,000,000	29,025,000
6	113, 3.800%	221	350,000,000		3,497,084		623,000	10/01/2012	10/01/2042	10/01/2012	10/01/2042	350,000,000	13,300,000
7	114, 4.600%	221	350,000,000		4,224,661		791,000	08/19/2013	08/15/2043	08/19/2013	08/15/2043	350,000,000	16,100,000
8	116, 4.700%	221	350,000,000		3,670,733		115,500	01/10/2014	01/15/2044	01/10/2014	01/15/2044	350,000,000	16,450,000
9	117, 3.100%	221	250,000,000		2,675,378		212,500	11/10/2014	11/01/2024	11/10/2014	11/01/2024	250,000,000	7,750,000
10	118, 3.700%	221	400,000,000		4,497,729			03/02/2015	03/01/2045	03/02/2015	03/01/2045	400,000,000	14,800,000
11	119, 4.350%	221	450,000,000		5,643,725		3,501,000	11/19/2015	11/15/2045	11/19/2015	11/15/2045	450,000,000	19,575,000
12	120, 2.550%	221	500,000,000		4,325,512			06/27/2016	06/15/2026	06/27/2016	06/15/2026	500,000,000	12,750,000
13	121, 3.650%	221	700,000,000		7,630,653		4,543,000	06/27/2016	06/15/2046	06/27/2016	06/15/2046	700,000,000	25,550,000
14	122, 2.950%	221	350,000,000		3,084,480		959,000	08/23/2017	08/15/2027	08/23/2017	08/15/2027	350,000,000	10,325,000
15	123, 3.750%	221	650,000,000		7,187,392		1,625,000	08/23/2017	08/15/2047	08/23/2017	08/15/2047	650,000,000	24,375,000
16	124, 4.000%	221	800,000,000		8,806,005		152,000	02/20/2018	03/01/2048	02/20/2018	03/01/2048	800,000,000	32,000,000
17	125, 3.700%	221	550,000,000		5,724,371		1,320,000	08/14/2018	08/15/2028	08/14/2018	08/15/2028	550,000,000	20,350,000
18	126, 4.000%	221	400,000,000		5,320,038		3,256,000	02/19/2019	03/01/2049	02/19/2019	03/01/2049	400,000,000	16,000,000
19	127, 3.200%	221	300,000,000		3,958,928		2,349,000	11/12/2019	11/15/2049	11/12/2019	11/15/2049	300,000,000	9,600,000
20	128, 2.200%	221	350,000,000		3,831,604		1,064,000	02/18/2020	03/01/2030	02/18/2020	03/01/2030	350,000,000	7,700,000
21	129, 3.000%	221	650,000,000		8,523,636		897,000	02/18/2020	03/01/2050	02/18/2020	03/01/2050	650,000,000	19,500,000
22	130, 3.125%	221	700,000,000		9,221,373		952,000	03/09/2021	03/15/2051	03/09/2021	03/15/2051	700,000,000	21,875,000
23	131, 2.750%	221	450,000,000		4,695,716		94,500	08/12/2021	09/01/2051	08/12/2021	09/01/2051	450,000,000	12,375,000
24	132, 3.150%	221	300,000,000		3,265,761		384,000	03/15/2022	03/15/2032	03/15/2022	03/15/2032	300,000,000	9,450,000
25	133, 3.850%	221	450,000,000		5,905,442		796,500	03/15/2022	03/15/2052	03/15/2022	03/15/2052	450,000,000	17,325,000
26	134, 4.900%	221	400,000,000		4,419,289		1,336,000	01/10/2023	02/01/2033	01/10/2023	02/01/2033	400,000,000	19,110,000
27	135, 5.300%	221	575,000,000		7,643,212		1,397,250	01/10/2023	02/01/2053	01/10/2023	02/01/2053	575,000,000	29,713,125
28	Subtotal		(a) 11,700,000,000		130,283,712		43,732,500					11,603,600,000	456,772,125
29	Reacquired Bonds (Account 222)
30
31
32
33	Subtotal
34	Advances from Associated Companies (Account 223)
35	Subordinated Deferrable Interest Debentures, 6.350%,	223	206,186,000		2,256,515		186,000	03/17/2003	03/15/2033	03/17/2003	03/15/2033	206,186,000	13,092,811
36	ComEd FInancing III
37	Subtotal		206,186,000		2,256,515		186,000					206,186,000	13,092,811
38	Other Long Term Debt (Account 224)
39
40
41
42	Subtotal
33	TOTAL		11,906,186,000									11,809,786,000	(b) 469,864,936

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: BondsPrincipalAmountIssued


Changes in Account 221 during the year:
	Issuances		Retirements
First Mortgage Bonds	$	975,000,000	$	—

The unamortized debt discount, premium or expense on reacquired debt are transferred to Account 189, Unamortized Loss on Reacquired Debt, or Account 257, Unamortized Gain on Reacquired Debt, as appropriate, and amortized to expense over the life of the new long-term debt issued to finance the debt redemption, and\or over the life of the original debt issuance if the debt is not refinanced.

(b) Concept: InterestExpenseOnLongTermDebtIssued


Total interest reported on Pages 256-257	$	469,864,936
Amortization of settled cash flow swaps - losses	519,507

Total for Accounts 427 and 430	$	470,384,443

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

RECONCILIATION OF REPORTED NET INCOME WITH TAXABLE INCOME FOR FEDERAL INCOME TAXES
Report the reconciliation of reported net income for the year with taxable income used in computing Federal income tax accruals and show computation of such tax accruals. Include in the reconciliation, as far as practicable, the same detail as furnished on Schedule M-1 of the tax return for the year. Submit a reconciliation even though there is no taxable income for the year. Indicate clearly the nature of each reconciling amount. If the utility is a member of a group which files a consolidated Federal tax return, reconcile reported net income with taxable net income as if a separate return were to be field, indicating, however, intercompany amounts to be eliminated in such a consolidated return. State names of group member, tax assigned to each group member, and basis of allocation, assignment, or sharing of the consolidated tax among the group members. A substitute page, designed to meet a particular need of a company, may be used as Long as the data is consistent and meets the requirements of the above instructions. For electronic reporting purposes complete Line 27 and provide the substitute Page in the context of a footnote.
Line No.	Particulars (Details) (a)	Amount (b)
1	Net Income for the Year (Page 117)	1,094,078,343
2	Reconciling Items for the Year
3
4	Taxable Income Not Reported on Books
5
6
7
8
9	Deductions Recorded on Books Not Deducted for Return
10	See footnote for details	(a) 313,674,397
14	Income Recorded on Books Not Included in Return
15
16
17
18
19	Deductions on Return Not Charged Against Book Income
20	See footnote for details	(b) 1,321,266,801
27	Federal Tax Net Income	86,485,939
28	Show Computation of Tax:
29	Federal Income Tax at 21%	18,162,047
30	See footnote for details	(c) 118,149,521
31	Total	136,311,568
32	Federal Income Tax Acct 409.10	129,557,732
33	Federal Income Tax Acct 409.20	6,753,836

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: DeductionsRecordedOnBooksNotDeductedForReturn


Net Income for the Year (Page 117)	$	1,094,078,343
Federal Income Tax	173,952,125
State Income Tax	139,722,272
Pre-tax Book Income	$	1,407,752,740

(b) Concept: DeductionsOnReturnNotChargedAgainstBookIncome


Increase (Decrease) in Taxable Income Resulting From:
Removal Costs	$	(187,217,362)
Mixed Service Costs	—
Repair Allowance - Unit of Property	(629,442,685)
Bonus Depreciation	—
Depreciation	211,594,007
CIAC	109,112,039
AFUDC Equity	(26,563,229)
AFUDC Debt	(38,477,582)
Capitalized Interest	47,915,630
Gain/Loss on Disposition of Property	(37,319,251)
Other (Property)	(6,320,290)
Regulatory Assets & Liabilities	(851,762,214)
Pension/OPEB/SERP	(474,726)
Accrued Liabilities	10,960,511
Merger Commitment Deferrals	—
State Income Taxes Deductible	28,751,890
Deferred Revenue	(397,734)
Fines & Penalties	—
Other (Net)	48,374,195

Total Schedule M's	$	(1,321,266,801)


Federal Taxable Income	$	86,485,939

Computation of Federal Income Tax:
Federal Income Tax on Current Year Income (21%)	$	18,162,047
Current Corporate Minimum Tax	118,023,568
Income Tax Credits Utilized	(5,843,485)
Net Operating Loss Utilized	—
Return to Accrual	1,920,027
Uncertain Tax Positions	2,930,709
2016-2021 R&D Affirmative	1,118,702
Federal Income Tax	$	136,311,568

Federal Income Tax Account 409.10	$	129,557,732
Federal Income Tax Account 409.20	6,753,836
Total	$	136,311,568

Additional information in response to Instruction 2, Page 261:

The Respondent is a wholly-owned subsidiary of Exelon Corporation. The Respondent files a consolidated tax return with Exelon Corporation and Exelon Corporation's other subsidiaries. The consolidated federal income tax liability was allocated to the Respondent on a separate-return basis. Corporate Alternative Minimum Tax Adjustment: This adjustment represents the difference between regular tax calculated at 21% of taxable income to the Corporate Alternative Minimum Tax calculated at 15% of Adjusted Financial Statement Income.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

TAXES ACCRUED, PREPAID AND CHARGES DURING YEAR
Give particulars (details) of the combined prepaid and accrued tax accounts and show the total taxes charged to operations and other accounts during the year. Do not include gasoline and other sales taxes which have been charged to the accounts to which the taxed material was charged. If the actual, or estimated amounts of such taxes are known, show the amounts in a footnote and designate whether estimated or actual amounts. Include on this page, taxes paid during the year and charged direct to final accounts, (not charged to prepaid or accrued taxes.) Enter the amounts in both columns (g) and (h). The balancing of this page is not affected by the inclusion of these taxes. Include in column (g) taxes charged during the year, taxes charged to operations and other accounts through (a) accruals credited to taxes accrued, (b)amounts credited to proportions of prepaid taxes chargeable to current year, and (c) taxes paid and charged direct to operations or accounts other than accrued and prepaid tax accounts. List the aggregate of each kind of tax in such manner that the total tax for each State and subdivision can readily be ascertained. If any tax (exclude Federal and State income taxes) covers more than one year, show the required information separately for each tax year, identifying the year in column (d). Enter all adjustments of the accrued and prepaid tax accounts in column (i) and explain each adjustment in a foot- note. Designate debit adjustments by parentheses. Do not include on this page entries with respect to deferred income taxes or taxes collected through payroll deductions or otherwise pending transmittal of such taxes to the taxing authority. Report in columns (l) through (o) how the taxes were distributed. Report in column (o) only the amounts charged to Accounts 408.1 and 409.1 pertaining to electric operations. Report in column (l) the amounts charged to Accounts 408.1 and 409.1 pertaining to other utility departments and amounts charged to Accounts 408.2 and 409.2. Also shown in column (o) the taxes charged to utility plant or other balance sheet accounts. For any tax apportioned to more than one utility department or account, state in a footnote the basis (necessity) of apportioning such tax.
					BALANCE AT BEGINNING OF YEAR					BALANCE AT END OF YEAR		DISTRIBUTION OF TAXES CHARGED
Line No.	DescriptionOfTaxesAccruedPrepaidAndCharged Kind of Tax (See Instruction 5) (a)	TypeOfTax Type of Tax (b)	TaxJurisdiction State (c)	TaxYear Tax Year (d)	TaxesAccrued Taxes Accrued (Account 236) (e)	PrepaidTaxes Prepaid Taxes (Include in Account 165) (f)	TaxesCharged Taxes Charged During Year (g)	TaxesPaid Taxes Paid During Year (h)	TaxAdjustments Adjustments (i)	TaxesAccrued Taxes Accrued (Account 236) (j)	PrepaidTaxes Prepaid Taxes (Included in Account 165) (k)	TaxesAccruedPrepaidAndCharged Electric (Account 408.1, 409.1) (l)	IncomeTaxesExtraordinaryItems Extraordinary Items (Account 409.3) (m)	AdjustmentsToRetainedEarnings Adjustment to Ret. Earnings (Account 439) (n)	TaxesIncurredOther Other (o)
1	Renewable Energy Tax	Other Taxes	IL	(a) 2023	695,421	0	4,625,837	4,638,737		682,521		4,625,837
2	Low Income Tax	Other Taxes	IL	(b) 2023	6,169,531	0	36,782,919	36,941,195		6,011,255		46,354,247			(q) 9,571,328
3	Energy Transition Assistance Charge	Other Taxes	IL	2023	9,022,399	0	58,936,053	60,205,034		7,753,418		58,936,053
4	Electricity Distribution Tax	Other Taxes	IL	(c) 2023	0	(o) 16,059,777	106,127,369	103,666,173		0	(p) 13,598,581	106,127,369
5	Chicago Infrastructure Maintenance Fee	Other Taxes	IL	(d) 2023	11,633,403	0	82,892,186	83,818,281		10,707,308		82,892,186
6	Evanston Infrastructure Maintenance Fee	Other Taxes	IL	(e) 2023	63,245	0	476,040	480,754		58,531		476,040
7	Municipal Utility Tax	Other Taxes	IL	(f) 2023	3,341,815	0	48,062	3,360,877		29,000		353,635			305,573
8	Cook County Parking Tax	Other Taxes	IL	(g) 2023	7,465	0	83,700	86,302		4,863		1,764			85,464
9	Chicago Transaction Tax	Other Taxes	IL	(h) 2023	19,202	0	546,428	522,869		42,761		238,328			308,100
10	Public Utility Fund	Other Taxes	IL	(i) 2023	1,369,065	0	1,460,045	1,341,769		1,487,341		1,460,045
11	Joliet Motor Fuel Tax	Other Taxes	IL	2023	0	0	118,379	4,772		113,607		118,379
12	Other Taxes	Other Taxes	IL	(j) 2023	2,688	0	251,690	10	248,992	0		251,690
13	Subtotal Other Tax				32,318,858	16,059,777	292,348,708	295,066,773	248,992	26,890,605	13,598,581	301,832,045			9,483,337
14	Unemployment Insurance (SUTA)	Unemployment Tax	IL	2022	30,499	0		30,499		0
15	Unemployment Insurance (SUTA)	Unemployment Tax	IL	2023	0	0	1,384,303	1,362,430		21,873		562,863			(r) 821,440
16	Unemployment Insurance (FUTA)	Unemployment Tax	Fed	2022	142,933	0		142,933		0
17	Unemployment Insurance (FUTA)	Unemployment Tax	Fed	2023	0	0	308,785	302,360		6,425		127,586			(s) 181,199
18	Subtotal Unemployment Tax				173,432	0	1,693,088	1,838,222		28,298		690,449			1,002,639
19	Use Tax	Sales And Use Tax	IL	(k) 2023	1,332,336	0	14,096,105	12,155,089		3,273,352		38,497			14,057,608
20	Chicago Use Tax	Sales And Use Tax	IL	(l) 2023	359,759	0	1,052,097	907,192		504,664		9,084			1,043,013
21	Sales Tax	Sales And Use Tax	IL	2023	0	162,492	358,432	376,920		0	180,980				358,432
22	Subtotal Sales And Use Tax				1,692,095	162,492	15,506,634	13,439,201		3,778,016	180,980	47,581			15,459,053
23	Federal Income Tax	Income Tax	Fed	(m) 2023	11,580,397	0	136,311,566	38,707,115	1,395,748	110,580,596		129,557,730			6,753,836
24	State Income Tax	Income Tax	IL	(n) 2023	3,260,658	0	10,137,127	28,290,203	367,907	21,045,827		11,432,424			1,295,297
25	Subtotal Income Tax				14,841,055	0	126,174,439	10,416,912	1,027,841	131,626,423		118,125,306			8,049,133
26	Federal Excise Tax - Heavy Highway	Excise Tax	Fed	2023	0	0	13,664	10,976	2,688	0		13,664
27	Subtotal Excise Tax				0	0	13,664	10,976	2,688	0		13,664
28	Franchise	Franchise Tax	IL	2022	0	1,547,544	1,547,544			0		1,547,544
29	Franchise	Franchise Tax	IL	2023	0	0	1,529,997	3,059,994		0	1,529,997	1,529,997
30	Subtotal Franchise Tax				0	1,547,544	3,077,541	3,059,994		0	1,529,997	3,077,541
31	Real Estate	Property Tax	IL	2022	36,205,407	0	3,918,487	32,286,920		0		3,918,487
32	Real Estate	Property Tax	IL	2023	0	0	36,255,000			36,255,000		35,921,223			(t) 333,777
33	Subtotal Other Property Tax				36,205,407	0	32,336,513	32,286,920		36,255,000		32,002,736			333,777
34	Vehicle License	Other License And Fees Tax	IL	2022	0	803,438	803,438			0					(u) 803,438
35	Vehicle License	Other License And Fees Tax	IL	2023	0	0	1,215,621	1,893,339		0	677,718				(v) 1,215,621
36	Vehicle License-Local	Other License And Fees Tax	IL	2022	0	79,461	79,461			0					(w) 79,461
37	Vehicle License-Local	Other License And Fees Tax	IL	2023	0	0	120,226	187,253		0	67,027				(x) 120,226
38	Subtotal Other License And Fees Tax				0	882,899	2,218,746	2,080,592		0	744,745				2,218,746
39	Insurance Contributions (FICA)	Payroll Tax	Fed	2022	10,922,863	0		10,922,863		0
40	Insurance Contributions (FICA)	Payroll Tax	Fed	2023	0	0	72,503,957	59,790,377		12,713,580		29,870,315			(y) 42,633,642
41	Subtotal Payroll Tax				10,922,863	0	72,503,957	70,713,240		12,713,580		29,870,315			42,633,642
40	TOTAL				96,153,710	18,652,712	545,873,290	428,912,830	776,161	211,291,922	16,054,303	485,659,637			60,213,653

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: TaxYear


The tax year for Renewable Energy Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(b) Concept: TaxYear


The tax year for Low Income Taxes accrued, prepaid, and charged during year also applies to the year 2022.


The tax year for Electricity Distribution Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(d) Concept: TaxYear


The tax year for Chicago Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(e) Concept: TaxYear


The tax year for Evanston Infrastructure Maintenance Fee Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(f) Concept: TaxYear


The tax year for Municipal Utility Taxes accrued, prepaid, and charged during year also applies to 2022 and prior years.

(g) Concept: TaxYear


The tax year for Cook County Parking Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(h) Concept: TaxYear


The tax year for Chicago Transaction Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(i) Concept: TaxYear

The tax year for Public Utility Fund Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(j) Concept: TaxYear


The tax year for Other Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(k) Concept: TaxYear


The tax year for Use Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(l) Concept: TaxYear


The tax year for Chicago Use Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(m) Concept: TaxYear


The tax year for Federal Income Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(n) Concept: TaxYear


The tax year for Illinois Income Taxes accrued, prepaid, and charged during year also applies to the year 2022.

(o) Concept: PrepaidTaxes


$6,567,897 recorded in Account 186 and $9,491,880 recorded in Account 143.

(p) Concept: PrepaidTaxes


$4,061,217 recorded in Account 186 and $9,537,364 recorded in Account 143.

(q) Concept: TaxesIncurredOther


Primarily Account 142.

(r) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

(s) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

(t) Concept: TaxesIncurredOther


Recorded to Account 408.2 for non-utility property and Account 131 for tax refunds.

(u) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

(v) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

(w) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

(x) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

(y) Concept: TaxesIncurredOther


Recorded to Account 184 and was subsequently allocated to various accounts.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ACCUMULATED DEFERRED INVESTMENT TAX CREDITS (Account 255)
Report below information applicable to Account 255. Where appropriate, segregate the balances and transactions by utility and nonutility operations. Explain by footnote any correction adjustments to the account balance shown in column (g). Include in column (i) the average period over which the tax credits are amortized.
			Deferred for Year		Allocations to Current Year's Income
Line No.	Account Subdivisions (a)	Balance at Beginning of Year (b)	Account No. (c)	Amount (d)	Account No. (e)	Amount (f)	Adjustments (g)	Balance at End of Year (h)	Average Period of Allocation to Income (i)	ADJUSTMENT EXPLANATION (j)
1	Electric Utility
2	3%								—
3	4%	45,646			411.4	1,598		47,244	45
4	7%								—
5	10%	5,984,465			411.4	1,170,385		4,814,080	32
6	Illinois ITC	1,630,491	255	367,902	411.4	49,416		1,948,977	41
8	TOTAL Electric (Enter Total of lines 2 thru 7)	7,660,602		367,902		1,218,203		6,810,301
9	Other (List separately and show 3%, 4%, 7%, 10% and TOTAL)
10										`
47	OTHER TOTAL
48	GRAND TOTAL	7,660,602		367,902		1,218,203		6,810,301

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

OTHER DEFERRED CREDITS (Account 253)
Report below the particulars (details) called for concerning other deferred credits. For any deferred credit being amortized, show the period of amortization. Minor items (5% of the Balance End of Year for Account 253 or amounts less than $100,000, whichever is greater) may be grouped by classes.
			DEBITS
Line No.	Description and Other Deferred Credits (a)	Balance at Beginning of Year (b)	Contra Account (c)	Amount (d)	Credits (e)	Balance at End of Year (f)
1	(a) Initial payments - contracts	3,940,593	454			3,940,593
2	(b) Deferred rents	2,796	931			2,796
3	Long-term contracting services	633,644	415			633,644
4	Long-term renewable energy
5	contracts	79,458,407	182.3	10,531,763	37,330,996	106,257,640
6	Funds for Utility Job
7	Training Program (FEJA)	10,000,000	557			10,000,000
8	Other	429,609	(c) Various	319,944,200	319,799,273	574,536
47	TOTAL	93,605,831		330,475,963	357,130,269	120,260,137

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: DescriptionOfOtherDeferredCredits


This item includes two contracts, with amortization periods starting April 1, 2000, and May 1, 2000, and continuing through March 31, 2030, and April 30, 2030, respectively.

(b) Concept: DescriptionOfOtherDeferredCredits


This item includes rents for various buildings, with amortization periods ranging from January 1, 1993 to December 31, 2023.


Other deferred credits are offset in Accounts 143, 242, 454, and 931.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ACCUMULATED DEFERRED INCOME TAXES - ACCELERATED AMORTIZATION PROPERTY (Account 281)

Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to amortizable property.
For other (Specify),include deferrals relating to other income and deductions.
Use footnotes as required.

CHANGES DURING YEAR

ADJUSTMENTS

Debits

Credits

Line No.

Account

(a)

Balance at Beginning of Year

(b)

Amounts Debited to Account 410.1

(c)

Amounts Credited to Account 411.1

(d)

Amounts Debited to Account 410.2

(e)

Amounts Credited to Account 411.2

(f)

Account Credited

(g)

Amount

(h)

Account Debited

(i)

Amount

(j)

Balance at End of Year

(k)

Accelerated Amortization (Account 281)

Electric

Defense Facilities

Pollution Control Facilities

Other

5.1

Other (provide details in footnote):

TOTAL Electric (Enter Total of lines 3 thru 7)

Gas

Defense Facilities

Pollution Control Facilities

Other

12.1

Other (provide details in footnote):

TOTAL Gas (Enter Total of lines 10 thru 14)

Other

16.1

Other

16.2

Other

TOTAL (Acct 281) (Total of 8, 15 and 16)

Classification of TOTAL

Federal Income Tax

State Income Tax

Local Income Tax

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ACCUMULATED DEFERRED INCOME TAXES - OTHER PROPERTY (Account 282)
Report the information called for below concerning the respondent’s accounting for deferred income taxes rating to property not subject to accelerated amortization. For other (Specify),include deferrals relating to other income and deductions. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 282
2	Electric	4,272,205,881	99,870,086	109,710,598			Primarily 182		Primarily 182	708,758,694	4,971,124,063
3	Gas
4	Other (Specify)
5	Total (Total of lines 2 thru 4)	4,272,205,881	99,870,086	109,710,598						708,758,694	(a) 4,971,124,063
6
7
8
9	TOTAL Account 282 (Total of Lines 5 thru 8)	4,272,205,881	99,870,086	109,710,598						708,758,694	4,971,124,063
10	Classification of TOTAL
11	Federal Income Tax	2,957,767,938	14,668,903	87,091,788						554,001,208	3,410,008,455
12	State Income Tax	1,314,437,943	114,538,989	22,618,810						154,757,486	1,561,115,608
13	Local Income Tax

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxesOtherProperty


Description:	Beginning Balance		Ending Balance
AFUDC Equity	$	46,558,350	$	63,954,946
CIAC	(252,901,666)		(156,724,498)
Plant Deferred Taxes - FAS 109	4,478,549,197		5,063,893,615
Total	$	4,272,205,881	$	4,971,124,063

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ACCUMULATED DEFERRED INCOME TAXES - OTHER (Account 283)
Report the information called for below concerning the respondent's accounting for deferred income taxes relating to amounts recorded in Account 283. For other (Specify),include deferrals relating to other income and deductions. Provide in the space below explanations for Page 276. Include amounts relating to insignificant items listed under Other. Use footnotes as required.
			CHANGES DURING YEAR				ADJUSTMENTS
							Debits		Credits
Line No.	Account (a)	Balance at Beginning of Year (b)	Amounts Debited to Account 410.1 (c)	Amounts Credited to Account 411.1 (d)	Amounts Debited to Account 410.2 (e)	Amounts Credited to Account 411.2 (f)	Account Credited (g)	Amount (h)	Account Debited (i)	Amount (j)	Balance at End of Year (k)
1	Account 283
2	Electric
3		1,007,638,245	439,682,066	102,058,622			190, 254, and 280	51,375,579	190, 254, and 280	52,488,019	1,346,374,129
9	TOTAL Electric (Total of lines 3 thru 8)	1,007,638,245	439,682,066	102,058,622				51,375,579		52,488,019	1,346,374,129
10	Gas
11
12
13
14
15
16
17	TOTAL Gas (Total of lines 11 thru 16)
18	TOTAL Other
19	TOTAL (Acct 283) (Enter Total of lines 9, 17 and 18)	1,007,638,245	439,682,066	102,058,622				(a) 51,375,579		52,488,019	1,346,374,129
20	Classification of TOTAL
21	Federal Income Tax	683,115,695	345,909,637	79,988,264			190, 254, and 280	51,375,579			897,661,489
22	State Income Tax	324,522,550	93,772,429	22,070,358					190, 254, and 280	52,488,019	448,712,640
23	Local Income Tax
NOTES

FOOTNOTE DATA

(a) Concept: AccumulatedDeferredIncomeTaxLiabilitiesOtherAdjustmentsDebitedToAccount


Description	Beginning Balance		Ending Balance
Pension Asset	$	340,928,200	$	347,053,474
Regulatory Asset	637,060,786		969,087,038
Unamortized Loss on Required Debt	5,768,521		4,681,661
Other	23,880,738		25,551,956
Total	$	1,007,638,245	$	1,346,374,129

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

OTHER REGULATORY LIABILITIES (Account 254)
Report below the particulars (details) called for concerning other regulatory liabilities, including rate order docket number, if applicable. Minor items (5% of the Balance in Account 254 at end of period, or amounts less than $100,000 which ever is less), may be grouped by classes. For Regulatory Liabilities being amortized, show period of amortization.
			DEBITS
Line No.	Description and Purpose of Other Regulatory Liabilities (a)	Balance at Beginning of Current Quarter/Year (b)	Account Credited (c)	Amount (d)	Credits (e)	Balance at End of Current Quarter/Year (f)
1	(a) Decommissioning the Regulatory Agreement Units	2,659,759,104	189		294,653,077	2,954,412,181
2	Purchased Electricity - Over Recovery		555	10,884,703	10,957,955	73,252
3	Zero Emissions Program	1,570,047	Revenue	1,570,047
4	Uncollectible Accounts Expense - Over Recovery	9,122,925	407.4	9,122,925
5	Deferred Income Taxes	2,005,066,274	190, 282, 283, 410, 411	111,707,199	284,311,635	2,177,670,710
6	Transmission Costs - Over Recovery	3,078,292	456.1	3,078,291	14,000,738	14,000,739
7	Renewable Portfolio Standard Costs - Rider REA	742,901,053	Revenue		290,209,440	1,033,110,493
8	Renewable Portfolio Standard Costs - ACP Funds	66,797,859	Revenue		2,259,310	69,057,169
9	Purchased Electricity - FERC 494 Refund	11,000,420	561.8	6,694,116		4,306,304
10	Parallel Operation of Retail Customer Generating Facilities Community Supply		555	3,126,680	3,126,680
11	Coal to Solar		557		912,324	912,324
41	TOTAL	5,499,295,974		146,183,961	900,431,159	6,253,543,172

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: DescriptionAndPurposeOfOtherRegulatoryLiabilities

Line Item

Rate Order Docket Number Or Recovery Mechanism

Amortization Period

Decommissioning the Regulatory Agreement Units

ICC Docket 00-0361

N/A

Purchased Electricity - Over Recovery

ICC Docket No. 05-0159 & 18-1824

4 months from period end

Zero Emissions Program

FEJA

9 months from each September

Uncollectible Accounts - Over Recovery

ICC Docket Nos. 09-0433 & 20-0309

12 months from each June

Deferred Income Taxes

ICC Order 18-0034 / FERC Order ER19-5 dated 4/26/19

Over the life of related assets

Transmission Costs - Over Recovery

FERC Docket ER07-583

12 months from each June

Renewable Portfolio Standard Costs - Rider REA

FEJA

9 months from each September

Renewable Portfolio Standard Costs - ACP Funds

IPA LTRRP approved by ICC

As approved by the IPA & ICC

Purchased Electricity - FERC 494 Refund

FERC Order Docket No. EL05-121-009

7/1/2018 - 12/31/2025

Parallel Operation of Retail Customer Generating Facilities Community Supply - L

ICC Docket 22-0305

Not determined yet

Coal to Solar

ICC Docket 12-0298

1/1/2014-12/31/2028

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

Electric Operating Revenues
The following instructions generally apply to the annual version of these pages. Do not report quarterly data in columns (c), (e), (f), and (g). Unbilled revenues and MWH related to unbilled revenues need not be reported separately as required in the annual version of these pages. Report below operating revenues for each prescribed account, and manufactured gas revenues in total. Report number of customers, columns (f) and (g), on the basis of meters, in addition to the number of flat rate accounts; except that where separate meter readings are added for billing purposes, one customer should be counted for each group of meters added. The average number of customers means the average of twelve figures at the close of each month. If increases or decreases from previous period (columns (c),(e), and (g)), are not derived from previously reported figures, explain any inconsistencies in a footnote. Disclose amounts of $250,000 or greater in a footnote for accounts 451, 456, and 457.2. Commercial and industrial Sales, Account 442, may be classified according to the basis of classification (Small or Commercial, and Large or Industrial) regularly used by the respondent if such basis of classification is not generally greater than 1000 Kw of demand. (See Account 442 of the Uniform System of Accounts. Explain basis of classification in a footnote.) See page 108, Important Changes During Period, for important new territory added and important rate increase or decreases. For Lines 2,4,5,and 6, see Page 304 for amounts relating to unbilled revenue by accounts. Include unmetered sales. Provide details of such Sales in a footnote.
Line No.	Title of Account (a)	Operating Revenues Year to Date Quarterly/Annual (b)	Operating Revenues Previous year (no Quarterly) (c)	MEGAWATT HOURS SOLD Year to Date Quarterly/Annual (d)	MEGAWATT HOURS SOLD Amount Previous year (no Quarterly) (e)	AVG.NO. CUSTOMERS PER MONTH Current Year (no Quarterly) (f)	AVG.NO. CUSTOMERS PER MONTH Previous Year (no Quarterly) (g)
1	SalesOfElectricityHeadingAbstract Sales of Electricity
2	ResidentialSalesAbstract (440) Residential Sales	3,862,275,761	3,438,822,318	26,022,565	27,818,982	3,732,459	3,713,755
3	CommercialAndIndustrialSalesAbstract (442) Commercial and Industrial Sales
4	CommercialSalesAbstract Small (or Comm.) (See Instr. 4)	2,027,198,786	1,250,665,489	28,705,593	29,766,349	391,406	390,683
5	IndustrialSalesAbstract Large (or Ind.) (See Instr. 4)	896,098,046	39,704,209	26,707,834	26,904,297	1,875	1,888
6	PublicStreetAndHighwayLightingAbstract (444) Public Street and Highway Lighting	45,348,653	32,602,901	454,308	470,865	4,796	4,846
7	OtherSalesToPublicAuthoritiesAbstract (445) Other Sales to Public Authorities
8	SalesToRailroadsAndRailwaysAbstract (446) Sales to Railroads and Railways	12,241,981	832,100	399,921	438,784	2	2
9	InterdepartmentalSalesAbstract (448) Interdepartmental Sales
10	SalesToUltimateConsumersAbstract TOTAL Sales to Ultimate Consumers	6,843,163,227	4,760,962,817	(f)(g) 82,290,221	(h) 85,399,277	4,130,538	4,111,174
11	SalesForResaleAbstract (447) Sales for Resale	27,394,838	66,890,074	988,910	1,117,149
12	SalesOfElectricityAbstract TOTAL Sales of Electricity	6,870,558,065	4,827,852,891	83,279,131	86,516,426	4,130,538	4,111,174
13	ProvisionForRateRefundsAbstract (Less) (449.1) Provision for Rate Refunds
14	RevenuesNetOfProvisionForRefundsAbstract TOTAL Revenues Before Prov. for Refunds	6,870,558,065	4,827,852,891	83,279,131	86,516,426	4,130,538	4,111,174
15	OtherOperatingRevenuesAbstract Other Operating Revenues
16	ForfeitedDiscounts (450) Forfeited Discounts	28,067,219	26,788,811
17	MiscellaneousServiceRevenues (451) Miscellaneous Service Revenues	(a) 19,161,315	(d) 16,889,543
18	SalesOfWaterAndWaterPower (453) Sales of Water and Water Power
19	RentFromElectricProperty (454) Rent from Electric Property	87,133,133	95,183,203
20	InterdepartmentalRents (455) Interdepartmental Rents
21	OtherElectricRevenue (456) Other Electric Revenues	(b) 10,583,695	(e) 9,905,388
22	RevenuesFromTransmissionOfElectricityOfOthers (456.1) Revenues from Transmission of Electricity of Others	831,947,358	821,355,622
23	RegionalTransmissionServiceRevenues (457.1) Regional Control Service Revenues
24	MiscellaneousRevenue (457.2) Miscellaneous Revenues
25	OtherMiscellaneousOperatingRevenues Other Miscellaneous Operating Revenues
26	OtherOperatingRevenues TOTAL Other Operating Revenues	976,892,720	970,122,567
27	ElectricOperatingRevenues TOTAL Electric Operating Revenues	(c) 7,847,450,785	5,797,975,458
Line12, column (b) includes $ 379,450,444 of unbilled revenues.
Line12, column (d) includes 158,499 MWH relating to unbilled revenues

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: MiscellaneousServiceRevenues



Account 451 (Miscellaneous Service Revenues) details are required by Page 300, Instruction No. 5
	For the Years Ended December 31,
	2023		2022
Meter Tampering	$	250,454	$	140,771
Temporary Service Revenues	3,905,485		2,879,367
Electric Choice & Other Data Service Fees	27,612		17,772
Turn On Charge	994,596		951,162
Returned Check Fees	1,390,351		1,184,444
Call Center Referral Services	114,569		109,042
Deferred Payment Agreement Reinstatement Fees	2,540,168		3,028,990
Energy Marketplace Services	209,095		327,838
Interconnection Application & Facility Study Fees	8,514,928		6,340,056
AMI Metering Opt-out Fees	1,061,222		1,213,360
Other	152,835		696,741
Total	$	19,161,315	$	16,889,543

(b) Concept: OtherElectricRevenue


Account 456 (Other Electric Revenues) details are required by Page 300, Instruction No. 5
	For the Years Ended December 31,
	2023		2022
Contracting & Engineering Study Services	$	9,794,273	$	4,440,268
IPP Electric Generation Studies reimbursements	517,586		3,206,326
Beneficial Electrification Incentives	(654,750)		0
Affiliate meter and other equipment rentals	12,611		87,298

Affiliate maintenance revenues	913,975		2,171,496


Total	$	10,583,695	$	9,905,388


Total Electric Operating Revenues include the following amounts included in ComEd's 2023 delivery services formula rate reconciliation:

Total Delivery Service Operating Revenue	$	3,395,873,000
2023 Estimated Reconciliation Recorded as of December 31, 2023	562,000,000		*
Low-Income Home Energy Assistance Program Revenue	48,814,000		*

* Amount included in Total Delivery Service Operating Revenue reported above

Total Electric Operating Revenues include the following amounts included in ComEd's 2023 energy efficiency formula rate reconciliation:

Total Energy Efficiency Operating Revenue	$	289,809,000
2023 Estimated Reconciliation Recorded as of December 31, 2023	16,249,000		*

* Amount included in Total Energy Efficiency Operating Revenue reported above

Total Electric Operating Revenues include the following amounts included in ComEd's 2023 distributed generation rebate formula rate reconciliation:

Total Distributed Generation Rebate Operating Revenue	$	14,277,000
2023 Estimated Reconciliation Recorded as of December 31, 2023	1,399,000		*

* Amount included in Total Distributed Generation Rebate Operating Revenue reported above

(d) Concept: MiscellaneousServiceRevenues



Refer to the footnote for Line No. 17, column b.

(e) Concept: OtherElectricRevenue


Refer to the footnote for Line No. 21, column b.

(f) Concept: MegawattHoursSoldSalesToUltimateConsumers


	MWh's for the Years Ended December 31,
	2023		2022
Retail deliveries for Full Service	$	29,964,172	$	31,414,991
Retail deliveries for Delivery Only	52,326,049		53,984,286
Total retail deliveries	$	82,290,221	$	85,399,277

General Notes:
Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from Alternative Retail Electric Suppliers.

(g) Concept: MegawattHoursSoldSalesToUltimateConsumers


Retail deliveries for Full Service	$	29,964,172
Retail deliveries for Delivery Only	52,326,049
Total Sales to Ultimate Customers	$	82,290,221

Refer to the footnote on Page 300, line No. 10, Column (d) for additional details.

(h) Concept: MegawattHoursSoldSalesToUltimateConsumers



Refer to the footnote for Line No. 10, column d.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

REGIONAL TRANSMISSION SERVICE REVENUES (Account 457.1)
The respondent shall report below the revenue collected for each service (i.e., control area administration, market administration, etc.) performed pursuant to a Commission approved tariff. All amounts separately billed must be detailed below.
Line No.	Description of Service (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	(a) BES - Residential	18,862,590	2,990,511,553	2,807,109	6,720	0.1585
2	BES - Residential Space Heating	1,518,069	195,873,224	151,055	10,050	0.1290
3	BES H - Hourly	390,285	46,940,326	42,261	9,235	0.1203
4	BES - Outdoor Lighting	5,152	1,048,293	5,308	971	0.2035
5	RDS - Delivery Service	5,413,007	411,203,718	726,726	7,448	0.0760
41	TOTAL Billed Residential Sales	26,189,103	3,645,577,114	3,732,459	7,017	0.1392
42	TOTAL Unbilled Rev. (See Instr. 6)	166,538	216,698,647			1.3012
43	TOTAL	26,022,565	3,862,275,761	3,732,459	6,972	0.1484

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: DescriptionOfNumberAndTitleOfRateSchedule


The following legend is applicable for the various rates shown in column (a) -
BES is Basic Electric Service
RDS is Retail Delivery Service

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	BES - Fixed	4,681,598	677,644,781	218,663	21,410	0.1447
2	BES H - Hourly	3,333,985	290,402,792	8,095	411,857	0.0871
3	BES - Outdoor Lighting	27,067	3,154,968	5,208	5,197	0.1166
4	RDS - Delivery Service	20,746,468	938,715,897	159,440	130,121	0.0452
41	TOTAL Billed Small or Commercial	28,789,118	1,909,918,438	391,406	73,553	0.0663
42	TOTAL Unbilled Rev. Small or Commercial (See Instr. 6)	83,525	117,280,348			1.4041
43	TOTAL Small or Commercial	28,705,593	2,027,198,786	391,406	73,340	0.0706

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	BES - Fixed	1,761	203,787	3	587,000	0.1157
2	BES H - Hourly	2,193,540	97,432,803	132	16,617,727	0.0444
3	BES - Outdoor Lighting
4	RDS - Delivery Service	24,456,702	760,217,324	1,740	14,055,576	0.0311
41	TOTAL Billed Large (or Ind.) Sales	26,652,003	857,853,914	1,875	14,214,402	0.0322
42	TOTAL Unbilled Rev. Large (or Ind.) (See Instr. 6)	55,831	38,244,132			0.6850
43	TOTAL Large (or Ind.)	26,707,834	896,098,046	1,875	14,244,178	0.0336

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	BES H - Hourly	78,736	11,941,410	834	94,408	0.1517
2	BES - Outdoor Lighting	44,722	8,873,015	2,573	17,381	0.1984
3	RDS - Delivery Service	330,653	19,928,120	1,389	238,051	0.0603
41	TOTAL Billed Public Street and Highway Lighting	454,111	40,742,545	4,796	94,685	0.0897
42	TOTAL Unbilled Rev. (See Instr. 6)	197	4,606,108			23.3813
43	TOTAL	454,308	45,348,653	4,796	94,726	0.0998

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
1	RDS - railroads	364,385	9,620,772	2	182,192,500	0.0264
41	TOTAL Billed Sales To Railroads and Railways	364,385	9,620,772	2	182,192,500	0.0264
42	TOTAL Unbilled Rev. (See Instr. 6)	35,536	2,621,209			0.0738
43	TOTAL	399,921	12,241,981	2	199,960,500	0.0306

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES OF ELECTRICITY BY RATE SCHEDULES
Report below for each rate schedule in effect during the year the MWH of electricity sold, revenue, average number of customer, average Kwh per customer, and average revenue per Kwh, excluding date for Sales for Resale which is reported on Page 310. Provide a subheading and total for each prescribed operating revenue account in the sequence followed in "Electric Operating Revenues," Page 300. If the sales under any rate schedule are classified in more than one revenue account, List the rate schedule and sales data under each applicable revenue account subheading. Where the same customers are served under more than one rate schedule in the same revenue account classification (such as a general residential schedule and an off peak water heating schedule), the entries in column (d) for the special schedule should denote the duplication in number of reported customers. The average number of customers should be the number of bills rendered during the year divided by the number of billing periods during the year (12 if all billings are made monthly). For any rate schedule having a fuel adjustment clause state in a footnote the estimated additional revenue billed pursuant thereto. Report amount of unbilled revenue as of end of year for each applicable revenue account subheading.
Line No.	Number and Title of Rate Schedule (a)	MWh Sold (b)	Revenue (c)	Average Number of Customers (d)	KWh of Sales Per Customer (e)	Revenue Per KWh Sold (f)
41	TOTAL Billed - All Accounts	82,448,720	6,463,712,783	4,130,538	19,961	0.0784
42	TOTAL Unbilled Rev. (See Instr. 6) - All Accounts	158,499	379,450,444			2.3940
43	TOTAL - All Accounts	(a) 82,290,221	6,843,163,227	4,130,538	19,922	0.0832

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: MegawattHoursOfElectricitySoldByRateSchedulesIncludingUnbilledRevenue


	MWh's for the Years Ended December 31,
	2023	2022
Retail Deliveries for Full Service	29,964,172	31,414,991
Retail Deliveries for Delivery Only	52,326,049	53,984,286
Total Retail Deliveries	82,290,221	85,399,277

General Notes: Full Service reflects deliveries to customers taking electric service under tariff rates. Delivery Only service reflects customers electing to receive electricity from a competitive electric generation supplier.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

SALES FOR RESALE (Account 447)
Report all sales for resale (i.e., sales to purchasers other than ultimate consumers) transacted on a settlement basis other than power exchanges during the year. Do not report exchanges of electricity ( i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges on this schedule. Power exchanges must be reported on the Purchased Power schedule (Page 326). Enter the name of the purchaser in column (a). Do note abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the purchaser. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projected load for this service in its system resource planning). In addition, the reliability of requirements service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for tong-term service. "Long-term" means five years or Longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for Long-term firm service which meets the definition of RQ service. For all transactions identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or setter can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service except that "intermediate-term" means longer than one year but Less than five years. SF - for short-term firm service. Use this category for all firm services where the duration of each period of commitment for service is one year or less. LU - for Long-term service from a designated generating unit. "Long-term" means five years or Longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service except that "intermediate-term" means Longer than one year but Less than five years. OS - for other service. use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote. AD - for Out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. Group requirements RQ sales together and report them starting at line number one. After listing all RQ sales, enter "Subtotal - RQ" in column (a). The remaining sales may then be listed in any order. Enter "Subtotal-Non-RQ" in column (a) after this Listing. Enter "Total'' in column (a) as the Last Line of the schedule. Report subtotals and total for columns (g) through (k). In Column (c), identify the FERC Rate Schedule or Tariff Number. On separate Lines, List all FERC rate schedules or tariffs under which service, as identified in column (b), is provided. For requirements RQ sales and any type of-service involving demand charges imposed on a monthly (or Longer) basis, enter the average monthly billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatt hours shown on bills rendered to the purchaser. Report demand charges in column (h), energy charges in column (i), and the total of any other types of charges, including out-of-period adjustments, in column (j). Explain in a footnote all components of the amount shown in column (j). Report in column (k) the total charge shown on bills rendered to the purchaser. The data in column (g) through (k) must be subtotaled based on the RQ/Non-RQ grouping (see instruction 4), and then totaled on the Last -line of the schedule. The "Subtotal - RQ" amount in column (g) must be reported as Requirements Sales For Resale on Page 401, line 23. The "Subtotal - Non-RQ" amount in column (g) must be reported as Non-Requirements Sales For Resale on Page 401,line 24. Footnote entries as required and provide explanations following all required data.
					ACTUAL DEMAND (MW)			REVENUE
Line No.	Name of Company or Public Authority (Footnote Affiliations) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Average Monthly Billing Demand (MW) (d)	Average Monthly NCP Demand (e)	Average Monthly CP Demand (f)	Megawatt Hours Sold (g)	Demand Charges ($) (h)	Energy Charges ($) (i)	Other Charges ($) (j)	Total ($) (h+i+j) (k)
1	Requirement Sales:
2	Non-Requirement Sales:
3	(a) PJM Interconnection, LLC	OS	PJM-1				988,910		27,394,838		27,394,838
15	Subtotal - RQ
16	Subtotal-Non-RQ						988,910		27,394,838		27,394,838
17	Total						988,910		27,394,838		27,394,838

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityReceivingElectricityPurchasedForResale


The MegaWatt Hours Sold and the associated Revenue Energy Charges reflect spot market sales.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

ELECTRIC OPERATION AND MAINTENANCE EXPENSES
If the amount for previous year is not derived from previously reported figures, explain in footnote.
Line No.	Account (a)	Amount for Current Year (b)	Amount for Previous Year (c) (c)
1	PowerProductionExpensesAbstract 1. POWER PRODUCTION EXPENSES
2	SteamPowerGenerationAbstract A. Steam Power Generation
3	SteamPowerGenerationOperationAbstract Operation
4	OperationSupervisionAndEngineeringSteamPowerGeneration (500) Operation Supervision and Engineering
5	FuelSteamPowerGeneration (501) Fuel
6	SteamExpensesSteamPowerGeneration (502) Steam Expenses
7	SteamFromOtherSources (503) Steam from Other Sources
8	SteamTransferredCredit (Less) (504) Steam Transferred-Cr.
9	ElectricExpensesSteamPowerGeneration (505) Electric Expenses
10	MiscellaneousSteamPowerExpenses (506) Miscellaneous Steam Power Expenses
11	RentsSteamPowerGeneration (507) Rents
12	Allowances (509) Allowances
13	SteamPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 4 thru 12)
14	SteamPowerGenerationMaintenanceAbstract Maintenance
15	MaintenanceSupervisionAndEngineeringSteamPowerGeneration (510) Maintenance Supervision and Engineering
16	MaintenanceOfStructuresSteamPowerGeneration (511) Maintenance of Structures
17	MaintenanceOfBoilerPlantSteamPowerGeneration (512) Maintenance of Boiler Plant
18	MaintenanceOfElectricPlantSteamPowerGeneration (513) Maintenance of Electric Plant
19	MaintenanceOfMiscellaneousSteamPlant (514) Maintenance of Miscellaneous Steam Plant
20	SteamPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 15 thru 19)
21	PowerProductionExpensesSteamPower TOTAL Power Production Expenses-Steam Power (Enter Total of Lines 13 & 20)
22	NuclearPowerGenerationAbstract B. Nuclear Power Generation
23	NuclearPowerGenerationOperationAbstract Operation
24	OperationSupervisionAndEngineeringNuclearPowerGeneration (517) Operation Supervision and Engineering
25	NuclearFuelExpense (518) Fuel
26	CoolantsAndWater (519) Coolants and Water
27	SteamExpensesNuclearPowerGeneration (520) Steam Expenses
28	SteamFromOtherSourcesNuclearPowerGeneration (521) Steam from Other Sources
29	SteamTransferredCreditNuclearPowerGeneration (Less) (522) Steam Transferred-Cr.
30	ElectricExpensesNuclearPowerGeneration (523) Electric Expenses
31	MiscellaneousNuclearPowerExpenses (524) Miscellaneous Nuclear Power Expenses
32	RentsNuclearPowerGeneration (525) Rents
33	NuclearPowerGenerationOperationsExpense TOTAL Operation (Enter Total of lines 24 thru 32)
34	NuclearPowerGenerationMaintenanceAbstract Maintenance
35	MaintenanceSupervisionAndEngineeringNuclearPowerGeneration (528) Maintenance Supervision and Engineering
36	MaintenanceOfStructuresNuclearPowerGeneration (529) Maintenance of Structures
37	MaintenanceOfReactorPlantEquipmentNuclearPowerGeneration (530) Maintenance of Reactor Plant Equipment
38	MaintenanceOfElectricPlantNuclearPowerGeneration (531) Maintenance of Electric Plant
39	MaintenanceOfMiscellaneousNuclearPlant (532) Maintenance of Miscellaneous Nuclear Plant
40	NuclearPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 35 thru 39)
41	PowerProductionExpensesNuclearPower TOTAL Power Production Expenses-Nuclear. Power (Enter Total of lines 33 & 40)
42	HydraulicPowerGenerationAbstract C. Hydraulic Power Generation
43	HydraulicPowerGenerationOperationAbstract Operation
44	OperationSupervisionAndEngineeringHydraulicPowerGeneration (535) Operation Supervision and Engineering
45	WaterForPower (536) Water for Power
46	HydraulicExpenses (537) Hydraulic Expenses
47	ElectricExpensesHydraulicPowerGeneration (538) Electric Expenses
48	MiscellaneousHydraulicPowerGenerationExpenses (539) Miscellaneous Hydraulic Power Generation Expenses
49	RentsHydraulicPowerGeneration (540) Rents
50	HydraulicPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 44 thru 49)
51	HydraulicPowerGenerationContinuedAbstract C. Hydraulic Power Generation (Continued)
52	HydraulicPowerGenerationMaintenanceAbstract Maintenance
53	MaintenanceSupervisionAndEngineeringHydraulicPowerGeneration (541) Mainentance Supervision and Engineering
54	MaintenanceOfStructuresHydraulicPowerGeneration (542) Maintenance of Structures
55	MaintenanceOfReservoirsDamsAndWaterways (543) Maintenance of Reservoirs, Dams, and Waterways
56	MaintenanceOfElectricPlantHydraulicPowerGeneration (544) Maintenance of Electric Plant
57	MaintenanceOfMiscellaneousHydraulicPlant (545) Maintenance of Miscellaneous Hydraulic Plant
58	HydraulicPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of lines 53 thru 57)
59	PowerProductionExpensesHydraulicPower TOTAL Power Production Expenses-Hydraulic Power (Total of Lines 50 & 58)
60	OtherPowerGenerationAbstract D. Other Power Generation
61	OtherPowerGenerationOperationAbstract Operation
62	OperationSupervisionAndEngineeringOtherPowerGeneration (546) Operation Supervision and Engineering
63	Fuel (547) Fuel
64	GenerationExpenses (548) Generation Expenses
64.1	OperationOfEnergyStorageEquipment (548.1) Operation of Energy Storage Equipment
65	MiscellaneousOtherPowerGenerationExpenses (549) Miscellaneous Other Power Generation Expenses
66	RentsOtherPowerGeneration (550) Rents
67	OtherPowerGenerationOperationsExpense TOTAL Operation (Enter Total of Lines 62 thru 67)
68	OtherPowerGenerationMaintenanceAbstract Maintenance
69	MaintenanceSupervisionAndEngineeringOtherPowerGeneration (551) Maintenance Supervision and Engineering
70	MaintenanceOfStructures (552) Maintenance of Structures
71	MaintenanceOfGeneratingAndElectricPlant (553) Maintenance of Generating and Electric Plant
71.1	MaintenanceOfEnergyStorageEquipmentOtherPowerGeneration (553.1) Maintenance of Energy Storage Equipment
72	MaintenanceOfMiscellaneousOtherPowerGenerationPlant (554) Maintenance of Miscellaneous Other Power Generation Plant
73	OtherPowerGenerationMaintenanceExpense TOTAL Maintenance (Enter Total of Lines 69 thru 72)
74	PowerProductionExpensesOtherPower TOTAL Power Production Expenses-Other Power (Enter Total of Lines 67 & 73)
75	OtherPowerSuplyExpensesAbstract E. Other Power Supply Expenses
76	PurchasedPower (555) Purchased Power	1,742,592,887	2,630,988,513
76.1	PowerPurchasedForStorageOperations (555.1) Power Purchased for Storage Operations
77	SystemControlAndLoadDispatchingElectric (556) System Control and Load Dispatching
78	OtherExpensesOtherPowerSupplyExpenses (557) Other Expenses	701,205,113	1,844,406,051
79	OtherPowerSupplyExpense TOTAL Other Power Supply Exp (Enter Total of Lines 76 thru 78)	2,443,798,000	786,582,462
80	PowerProductionExpenses TOTAL Power Production Expenses (Total of Lines 21, 41, 59, 74 & 79)	2,443,798,000	786,582,462
81	TransmissionExpensesAbstract 2. TRANSMISSION EXPENSES
82	TransmissionExpensesOperationAbstract Operation
83	OperationSupervisionAndEngineeringElectricTransmissionExpenses (560) Operation Supervision and Engineering	26,886,530	25,668,154
85	LoadDispatchReliability (561.1) Load Dispatch-Reliability
86	LoadDispatchMonitorAndOperateTransmissionSystem (561.2) Load Dispatch-Monitor and Operate Transmission System
87	LoadDispatchTransmissionServiceAndScheduling (561.3) Load Dispatch-Transmission Service and Scheduling
88	SchedulingSystemControlAndDispatchServices (561.4) Scheduling, System Control and Dispatch Services	397,423,917	378,924,480
89	ReliabilityPlanningAndStandardsDevelopment (561.5) Reliability, Planning and Standards Development
90	TransmissionServiceStudies (561.6) Transmission Service Studies	24,238	436,849
91	GenerationInterconnectionStudies (561.7) Generation Interconnection Studies	357,679	2,004,647
92	ReliabilityPlanningAndStandardsDevelopmentServices (561.8) Reliability, Planning and Standards Development Services	15,259,248	15,989,983
93	StationExpensesTransmissionExpense (562) Station Expenses	2,597,339	2,494,512
93.1	OperationOfEnergyStorageEquipmentTransmissionExpense (562.1) Operation of Energy Storage Equipment
94	OverheadLineExpense (563) Overhead Lines Expenses	390,000	30,731
95	UndergroundLineExpensesTransmissionExpense (564) Underground Lines Expenses	324,074	418,731
96	TransmissionOfElectricityByOthers (565) Transmission of Electricity by Others	10,659,454	8,919,712
97	MiscellaneousTransmissionExpenses (566) Miscellaneous Transmission Expenses	(a) 25,596,876	(c) 20,493,947
98	RentsTransmissionElectricExpense (567) Rents	1,428,087	1,301,817
99	TransmissionOperationExpense TOTAL Operation (Enter Total of Lines 83 thru 98)	480,167,442	456,622,101
100	TransmissionMaintenanceAbstract Maintenance
101	MaintenanceSupervisionAndEngineeringElectricTransmissionExpenses (568) Maintenance Supervision and Engineering	1,463,052	2,414,182
102	MaintenanceOfStructuresTransmissionExpense (569) Maintenance of Structures	1,397,640	964,313
103	MaintenanceOfComputerHardwareTransmission (569.1) Maintenance of Computer Hardware	299,080	279,203
104	MaintenanceOfComputerSoftwareTransmission (569.2) Maintenance of Computer Software	1,804,347	2,692,024
105	MaintenanceOfCommunicationEquipmentElectricTransmission (569.3) Maintenance of Communication Equipment	495,512	522,850
106	MaintenanceOfMiscellaneousRegionalTransmissionPlant (569.4) Maintenance of Miscellaneous Regional Transmission Plant
107	MaintenanceOfStationEquipmentTransmission (570) Maintenance of Station Equipment	24,010,672	23,928,282
107.1	MaintenanceOfEnergyStorageEquipmentTransmission (570.1) Maintenance of Energy Storage Equipment
108	MaintenanceOfOverheadLinesTransmission (571) Maintenance of Overhead Lines	25,958,394	24,589,105
109	MaintenanceOfUndergroundLinesTransmission (572) Maintenance of Underground Lines	2,067,106	2,421,743
110	MaintenanceOfMiscellaneousTransmissionPlant (573) Maintenance of Miscellaneous Transmission Plant	8,959,648	5,237,585
111	TransmissionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 101 thru 110)	66,455,451	63,049,287
112	TransmissionExpenses TOTAL Transmission Expenses (Total of Lines 99 and 111)	546,622,893	519,671,388
113	RegionalMarketExpensesAbstract 3. REGIONAL MARKET EXPENSES
114	RegionalMarketExpensesOperationAbstract Operation
115	OperationSupervision (575.1) Operation Supervision
116	DayAheadAndRealTimeMarketAdministration (575.2) Day-Ahead and Real-Time Market Facilitation
117	TransmissionRightsMarketAdministration (575.3) Transmission Rights Market Facilitation
118	CapacityMarketAdministration (575.4) Capacity Market Facilitation
119	AncillaryServicesMarketAdministration (575.5) Ancillary Services Market Facilitation
120	MarketMonitoringAndCompliance (575.6) Market Monitoring and Compliance
121	MarketFacilitationMonitoringAndComplianceServices (575.7) Market Facilitation, Monitoring and Compliance Services	6,841,512	6,591,797
122	RentsRegionalMarketExpenses (575.8) Rents
123	RegionalMarketOperationExpense Total Operation (Lines 115 thru 122)	6,841,512	6,591,797
124	RegionalMarketExpensesMaintenanceAbstract Maintenance
125	MaintenanceOfStructuresAndImprovementsRegionalMarketExpenses (576.1) Maintenance of Structures and Improvements
126	MaintenanceOfComputerHardware (576.2) Maintenance of Computer Hardware
127	MaintenanceOfComputerSoftware (576.3) Maintenance of Computer Software
128	MaintenanceOfCommunicationEquipmentRegionalMarketExpenses (576.4) Maintenance of Communication Equipment
129	MaintenanceOfMiscellaneousMarketOperationPlant (576.5) Maintenance of Miscellaneous Market Operation Plant
130	RegionalMarketMaintenanceExpense Total Maintenance (Lines 125 thru 129)
131	RegionalMarketExpenses TOTAL Regional Transmission and Market Operation Expenses (Enter Total of Lines 123 and 130)	6,841,512	6,591,797
132	DistributionExpensesAbstract 4. DISTRIBUTION EXPENSES
133	DistributionExpensesOperationAbstract Operation
134	OperationSupervisionAndEngineeringDistributionExpense (580) Operation Supervision and Engineering	26,273,230	24,656,189
135	LoadDispatching (581) Load Dispatching	81,592	72,831
136	StationExpensesDistribution (582) Station Expenses	1,367,288	1,378,866
137	OverheadLineExpenses (583) Overhead Line Expenses	3,090,935	4,156,285
138	UndergroundLineExpenses (584) Underground Line Expenses	20,013,201	20,068,180
138.1	OperationOfEnergyStorageEquipmentDistribution (584.1) Operation of Energy Storage Equipment
139	StreetLightingAndSignalSystemExpenses (585) Street Lighting and Signal System Expenses	2,328,703	1,499,284
140	MeterExpenses (586) Meter Expenses	9,988,294	6,924,399
141	CustomerInstallationsExpenses (587) Customer Installations Expenses	18,598,507	23,098,242
142	MiscellaneousDistributionExpenses (588) Miscellaneous Expenses	106,833,329	119,740,754
143	RentsDistributionExpense (589) Rents	4,283,656	3,092,721
144	DistributionOperationExpensesElectric TOTAL Operation (Enter Total of Lines 134 thru 143)	192,858,735	204,687,751
145	DistributionExpensesMaintenanceAbstract Maintenance
146	MaintenanceSupervisionAndEngineering (590) Maintenance Supervision and Engineering	6,584,314	6,175,230
147	MaintenanceOfStructuresDistributionExpense (591) Maintenance of Structures	2,043,511	2,072,901
148	MaintenanceOfStationEquipment (592) Maintenance of Station Equipment	43,855,527	43,088,550
148.1	MaintenanceOfEnergyStorageEquipment (592.2) Maintenance of Energy Storage Equipment
149	MaintenanceOfOverheadLines (593) Maintenance of Overhead Lines	223,450,528	214,160,829
150	MaintenanceOfUndergroundLines (594) Maintenance of Underground Lines	55,416,786	54,237,004
151	MaintenanceOfLineTransformers (595) Maintenance of Line Transformers	6,818,851	5,789,737
152	MaintenanceOfStreetLightingAndSignalSystems (596) Maintenance of Street Lighting and Signal Systems	2,433,605	2,376,160
153	MaintenanceOfMeters (597) Maintenance of Meters	1,167,490	1,312,309
154	MaintenanceOfMiscellaneousDistributionPlant (598) Maintenance of Miscellaneous Distribution Plant	9,962,073	9,344,810
155	DistributionMaintenanceExpenseElectric TOTAL Maintenance (Total of Lines 146 thru 154)	351,732,685	338,557,530
156	DistributionExpenses TOTAL Distribution Expenses (Total of Lines 144 and 155)	544,591,420	543,245,281
157	CustomerAccountsExpensesAbstract 5. CUSTOMER ACCOUNTS EXPENSES
158	CustomerAccountsExpensesOperationsAbstract Operation
159	SupervisionCustomerAccountExpenses (901) Supervision	336,289	378,241
160	MeterReadingExpenses (902) Meter Reading Expenses	16,440,582	18,245,045
161	CustomerRecordsAndCollectionExpenses (903) Customer Records and Collection Expenses	197,074,440	176,980,949
162	UncollectibleAccounts (904) Uncollectible Accounts	44,780,156	24,305,686
163	MiscellaneousCustomerAccountsExpenses (905) Miscellaneous Customer Accounts Expenses
164	CustomerAccountExpenses TOTAL Customer Accounts Expenses (Enter Total of Lines 159 thru 163)	258,631,467	219,909,921
165	CustomerServiceAndInformationalExpensesAbstract 6. CUSTOMER SERVICE AND INFORMATIONAL EXPENSES
166	CustomerServiceAndInformationalExpensesOperationAbstract Operation
167	SupervisionCustomerServiceAndInformationExpenses (907) Supervision
168	CustomerAssistanceExpenses (908) Customer Assistance Expenses	37,985,667	31,907,881
169	InformationalAndInstructionalAdvertisingExpenses (909) Informational and Instructional Expenses	12,655,336	12,270,186
170	MiscellaneousCustomerServiceAndInformationalExpenses (910) Miscellaneous Customer Service and Informational Expenses
171	CustomerServiceAndInformationExpenses TOTAL Customer Service and Information Expenses (Total Lines 167 thru 170)	50,641,003	44,178,067
172	SalesExpenseAbstract 7. SALES EXPENSES
173	SalesExpenseOperationAbstract Operation
174	SupervisionSalesExpense (911) Supervision
175	DemonstratingAndSellingExpenses (912) Demonstrating and Selling Expenses
176	AdvertisingExpenses (913) Advertising Expenses
177	MiscellaneousSalesExpenses (916) Miscellaneous Sales Expenses
178	SalesExpenses TOTAL Sales Expenses (Enter Total of Lines 174 thru 177)
179	AdministrativeAndGeneralExpensesAbstract 8. ADMINISTRATIVE AND GENERAL EXPENSES
180	AdministrativeAndGeneralExpensesOperationAbstract Operation
181	AdministrativeAndGeneralSalaries (920) Administrative and General Salaries	54,461,993	48,851,634
182	OfficeSuppliesAndExpenses (921) Office Supplies and Expenses	24,072,201	22,713,540
183	AdministrativeExpensesTransferredCredit (Less) (922) Administrative Expenses Transferred-Credit	55,017,767	42,518,604
184	OutsideServicesEmployed (923) Outside Services Employed	247,635,892	220,765,519
185	PropertyInsurance (924) Property Insurance	2,272,568	2,291,440
186	InjuriesAndDamages (925) Injuries and Damages	20,785,264	8,642,655
187	EmployeePensionsAndBenefits (926) Employee Pensions and Benefits	74,976,530	85,300,246
188	FranchiseRequirements (927) Franchise Requirements	37,509,540	41,385,838
189	RegulatoryCommissionExpenses (928) Regulatory Commission Expenses	9,224,259	2,954,820
190	DuplicateChargesCredit (929) (Less) Duplicate Charges-Cr.	37,509,540	41,385,838
191	GeneralAdvertisingExpenses (930.1) General Advertising Expenses	8,455,675	7,226,630
192	MiscellaneousGeneralExpenses (930.2) Miscellaneous General Expenses	10,424,781	14,560,234
193	RentsAdministrativeAndGeneralExpense (931) Rents	2,721,104	3,568,021
194	AdministrativeAndGeneralOperationExpense TOTAL Operation (Enter Total of Lines 181 thru 193)	400,012,500	374,356,135
195	AdministrativeAndGeneralExpensesMaintenanceAbstract Maintenance
196	MaintenanceOfGeneralPlant (935) Maintenance of General Plant	41,192,422	42,605,388
197	AdministrativeAndGeneralExpenses TOTAL Administrative & General Expenses (Total of Lines 194 and 196)	441,204,922	416,961,523
198	OperationsAndMaintenanceExpensesElectric TOTAL Electric Operation and Maintenance Expenses (Total of Lines 80, 112, 131, 156, 164, 171, 178, and 197)	(b) 4,292,331,217	(d) 2,537,140,439

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: MiscellaneousTransmissionExpenses


Included in Account 566 (Miscellaneous Transmission Expense) are expenses (benefits) associated with the following:
	For the Years Ended December 31,
	2023		2022
PJM Interconnection, LLC (PJM) Related Activity:
PJM Transmission benefit	$	—	$	(617,438)

Other	(1,318,398)		(5,888,919)
Sub-total (PJM related activity)	$	(1,318,398)	$	(6,506,357)
Other Miscellaneous transmission expenses	26,915,274		27,000,304
Total for Account 566	$	25,596,876	$	20,493,947

Expenses associated with PJM were recorded in the following accounts:
	For the Years Ended December 31,
	2023		2022
Account 555	$	691,537,366	$	1,308,487,075
Account 561.4	397,423,917		378,924,480
Account 561.8	15,259,248		15,989,983
Account 566	(1,318,398)		(6,506,357)
Account 575.7	6,841,513		6,591,797
Total	$	1,109,743,646	$	1,703,486,978

(b) Concept: OperationsAndMaintenanceExpensesElectric


Includes expenses for the year 2023 related to the following:
Postretirement benefit expenses, other than pension expenses (PBOP), of ($5,587,089)
Power procurement expenses of $295,182 in A&G accounts 920-935.


Refer to the footnote for Line No. 97, Column (b).

(d) Concept: OperationsAndMaintenanceExpensesElectric


Includes expenses for the year 2022 related to the following:
Postretirement benefit expenses, other than pension expenses (PBOP), of ($1,629,074)
Power procurement expenses of $504,677 in A&G accounts 920-935.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

PURCHASED POWER (Account 555)
Report all power purchases made during the year. Also report exchanges of electricity (i.e., transactions involving a balancing of debits and credits for energy, capacity, etc.) and any settlements for imbalanced exchanges. Enter the name of the seller or other party in an exchange transaction in column (a). Do not abbreviate or truncate the name or use acronyms. Explain in a footnote any ownership interest or affiliation the respondent has with the seller. In column (b), enter a Statistical Classification Code based on the original contractual terms and conditions of the service as follows: RQ - for requirements service. Requirements service is service which the supplier plans to provide on an ongoing basis (i.e., the supplier includes projects load for this service in its system resource planning). In addition, the reliability of requirement service must be the same as, or second only to, the supplier's service to its own ultimate consumers. LF - for long-term firm service. "Long-term" means five years or longer and "firm" means that service cannot be interrupted for economic reasons and is intended to remain reliable even under adverse conditions (e.g., the supplier must attempt to buy emergency energy from third parties to maintain deliveries of LF service). This category should not be used for long-term firm service firm service which meets the definition of RQ service. For all transaction identified as LF, provide in a footnote the termination date of the contract defined as the earliest date that either buyer or seller can unilaterally get out of the contract. IF - for intermediate-term firm service. The same as LF service expect that "intermediate-term" means longer than one year but less than five years. SF - for short-term service. Use this category for all firm services, where the duration of each period of commitment for service is one year or less. LU - for long-term service from a designated generating unit. "Long-term" means five years or longer. The availability and reliability of service, aside from transmission constraints, must match the availability and reliability of the designated unit. IU - for intermediate-term service from a designated generating unit. The same as LU service expect that "intermediate-term" means longer than one year but less than five years. EX - For exchanges of electricity. Use this category for transactions involving a balancing of debits and credits for energy, capacity, etc. and any settlements for imbalanced exchanges. OS - for other service. Use this category only for those services which cannot be placed in the above-defined categories, such as all non-firm service regardless of the Length of the contract and service from designated units of Less than one year. Describe the nature of the service in a footnote for each adjustment. AD - for out-of-period adjustment. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting years. Provide an explanation in a footnote for each adjustment. In column (c), identify the FERC Rate Schedule Number or Tariff, or, for non-FERC jurisdictional sellers, include an appropriate designation for the contract. On separate lines, list all FERC rate schedules, tariffs or contract designations under which service, as identified in column (b), is provided. For requirements RQ purchases and any type of service involving demand charges imposed on a monnthly (or longer) basis, enter the monthly average billing demand in column (d), the average monthly non-coincident peak (NCP) demand in column (e), and the average monthly coincident peak (CP) demand in column (f). For all other types of service, enter NA in columns (d), (e) and (f). Monthly NCP demand is the maximum metered hourly (60-minute integration) demand in a month. Monthly CP demand is the metered demand during the hour (60-minute integration) in which the supplier's system reaches its monthly peak. Demand reported in columns (e) and (f) must be in megawatts. Footnote any demand not stated on a megawatt basis and explain. Report in column (g) the megawatthours shown on bills rendered to the respondent, excluding purchases for energy storage. Report in column (h) the megawatthours shown on bills rendered to the respondent for energy storage purchases. Report in columns (i) and (j) the megawatthours of power exchanges received and delivered, used as the basis for settlement. Do not report net exchange. Report demand charges in column (k), energy charges in column (l), and the total of any other types of charges, including out-of-period adjustments, in column (m). Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills received as settlement by the respondent. For power exchanges, report in column (n) the settlement amount for the net receipt of energy. If more energy was delivered than received, enter a negative amount. If the settlement amount (m) include credits or charges other than incremental generation expenses, or (2) excludes certain credits or charges covered by the agreement, provide an explanatory footnote. The data in columns (g) through (n) must be totaled on the last line of the schedule. The total amount in columns (g) and (h) must be reported as Purchases on Page 401, line 10. The total amount in column (i) must be reported as Exchange Received on Page 401, line 12. The total amount in column (j) must be reported as Exchange Delivered on Page 401, line 13. Footnote entries as required and provide explanations following all required data.
					Actual Demand (MW)				POWER EXCHANGES		COST/SETTLEMENT OF POWER
Line No.	NameOfCompanyOrPublicAuthorityProvidingPurchasedPower Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	RateScheduleTariffNumber Ferc Rate Schedule or Tariff Number (c)	AverageMonthlyBillingDemand Average Monthly Billing Demand (MW) (d)	AverageMonthlyNonCoincidentPeakDemand Average Monthly NCP Demand (e)	AverageMonthlyCoincidentPeakDemand Average Monthly CP Demand (f)	MegawattHoursPurchasedOtherThanStorage MegaWatt Hours Purchased (Excluding for Energy Storage) (g)	MegawattHoursPurchasedForEnergyStorage MegaWatt Hours Purchased for Energy Storage (h)	EnergyReceivedThroughPowerExchanges MegaWatt Hours Received (i)	EnergyDeliveredThroughPowerExchanges MegaWatt Hours Delivered (j)	DemandChargesOfPurchasedPower Demand Charges ($) (k)	EnergyChargesOfPurchasedPower Energy Charges ($) (l)	OtherChargesOfPurchasedPower Other Charges ($) (m)	SettlementOfPower Total (k+l+m) of Settlement ($) (n)
1	(a) AEP Energy Partners, Inc.	OS					571,400					33,376,194		33,376,194
2	Dynegy Marketing ad Trade, LLC	OS					2,971,325					164,158,891		164,158,891
3	Enel Trading North America, LLC	OS					17,800					912,640		912,640
4	(b) Constellation Energy Generation, LLC	OS					2,674,800					97,905,145		97,905,145
5	J. ARON & COMPANY LLC	OS					1,646,325					176,841,656		176,841,656
6	Macquarie Energy, LLC	OS					1,227,850					80,510,938		80,510,938
7	Midwest Generation, LLC	OS					955,400					27,425,920		27,425,920
8	Morgan Stanley Capital Group Inc.	OS					1,593,575					44,483,018		44,483,018
9	Mercuria Energy America, LLC	OS					48,400					1,430,916		1,430,916
10	NextEra Energy Marketing, LLC	OS					958,900					46,691,254		46,691,254
11	NRG Power Marketing, LLC	OS					1,969,925					116,269,182		116,269,182
12	Shell Energy North America (US), L.P.	OS					1,304,425					66,808,732		66,808,732
13	Tidal	OS					364,225					27,269,294		27,269,294
14	TransAlta Energy Marketing (U.S.) Inc.	OS					740,525					61,946,251		61,946,251
15	Vitol Inc.	OS					102,200					14,170,120		14,170,120
16	Cogeneration	OS					379,141					24,664,975		24,664,975
17	PJM Interconnection, LLC	OS					15,229,684					691,537,365		691,537,365
18	Company Use	OS
19	Deferred Energy Costs	OS											(c) 16,093,934	16,093,934
20	Other Net Metering Arrangements						213,570						(d) 9,358,316	9,358,316
21	Other Miscellaneous Adjustments	OS											72,926,014	72,926,014
15	TOTAL						(e) 32,969,470	0	0	0		1,676,402,491	66,190,396	1,742,592,887

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower


This footnote pertains to Column (a) of Pages 326. Refer to Notes to Financial Statements, Page 122-123, for information regarding the Respondent's energy procurement for retail customers pursuant to the ICC-approved procurement process.

(b) Concept: NameOfCompanyOrPublicAuthorityProvidingPurchasedPower


Constellation Energy Generation, LLC (formerly Exelon Generation Company, LLC) was a subsidiary of Exelon Corporation until February 1, 2022.





The Respondent's electricity costs are recoverable or refundable under the Respondent's ICC approved rates. The Respondent recovers or refunds the difference between the actual cost of electricity and the amount included in rates. Differences between the amounts billed to customers and the actual costs recoverable are deferred and recovered or refunded in future periods by means of prospective monthly adjustments to rates.

(d) Concept: OtherChargesOfPurchasedPower


Represents the settlement activity associated with the 20-year floating-to-fixed energy swap contracts entered into on December 17, 2010 with unaffiliated suppliers for the procurement of long-term renewable energy and associated RECs.

(e) Concept: MegawattHoursPurchasedOtherThanStorage


Reflects utility zone load, which includes the following amounts purchased by ComEd to serve its Full Service customers.

	1Q 2023 Month	MWhs
	January	2,869,396
	February	2,610,865
	March	2,657,711
	Quarter Total	8,137,972

	2Q 2023 Month	MWhs
	April	2,177,825
	May	2,276,382
	June	2,770,877
	Quarter Total	7,225,084

	3Q 2023 Month	MWhs
	July	3,617,373
	August	3,868,648
	September	3,161,863
	Quarter Total	10,647,884

	4Q 2023 Month	MWhs
	October	1,946,443
	November	2,363,638
	December	2,648,449
	Quarter Total	6,958,530

	YTD Total	32,969,470

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

TRANSMISSION OF ELECTRICITY FOR OTHERS (Account 456.1) (Including transactions referred to as "wheeling")

Report all transmission of electricity, i.e., wheeling, provided for other electric utilities, cooperatives, other public authorities, qualifying facilities, non-traditional utility suppliers and ultimate customers for the quarter.
Use a separate line of data for each distinct type of transmission service involving the entities listed in column (a), (b) and (c).
Report in column (a) the company or public authority that paid for the transmission service. Report in column (b) the company or public authority that the energy was received from and in column (c) the company or public authority that the energy was delivered to. Provide the full name of each company or public authority. Do not abbreviate or truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation the respondent has with the entities listed in columns (a), (b) or (c).
In column (d) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO - Firm Network Service for Others, FNS - Firm Network Transmission Service for Self, LFP - "Long-Term Firm Point to Point Transmission Service, OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point to Point Transmission Reservation, NF - non-firm transmission service, OS - Other Transmission Service and AD - Out-of-Period Adjustments. Use this code for any accounting adjustments or "true-ups" for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes.
In column (e), identify the FERC Rate Schedule or Tariff Number, On separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (d), is provided.
Report receipt and delivery locations for all single contract path, "point to point" transmission service. In column (f), report the designation for the substation, or other appropriate identification for where energy was received as specified in the contract. In column (g) report the designation for the substation, or other appropriate identification for where energy was delivered as specified in the contract.
Report in column (h) the number of megawatts of billing demand that is specified in the firm transmission service contract. Demand reported in column (h) must be in megawatts. Footnote any demand not stated on a megawatts basis and explain.
Report in column (i) and (j) the total megawatthours received and delivered.
In column (k) through (n), report the revenue amounts as shown on bills or vouchers. In column (k), provide revenues from demand charges related to the billing demand reported in column (h). In column (I), provide revenues from energy charges related to the amount of energy transferred. In column (m), provide the total revenues from all other charges on bills or vouchers rendered, including out of period adjustments. Explain in a footnote all components of the amount shown in column (m). Report in column (n) the total charge shown on bills rendered to the entity Listed in column (a). If no monetary settlement was made, enter zero (0) in column (n). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered.
The total amounts in columns (i) and (j) must be reported as Transmission Received and Transmission Delivered for annual report purposes only on Page 401, Lines 16 and 17, respectively.
Footnote entries and provide explanations following all required data.

TRANSFER OF ENERGY

REVENUE FROM TRANSMISSION OF ELECTRICITY FOR OTHERS

Line No.

(a)

(b)

(c)

(d)

(e)

(f)

(g)

(h)

(i)

(j)

(k)

(l)

(m)

(n)

PJM Interconnection L.L.C.

FNO

PJM OATT

(a)

116,086,890

PJM Interconnection L.L.C.

FNS

PJM OATT

(b)

100,815,748

PJM Interconnection L.L.C.

PJM OATT

(c)

6,395,269

TOTAL

223,297,907

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers


Network Integration Transmission Service (NITS) for Third Party Suppliers (difference between NITS Credits and Provider of Last Resort Network Integration Charges).

(b) Concept: OtherChargesRevenueTransmissionOfElectricityForOthers


Network Integration Transmission Service (NITS) for Self.


The details of the Other Transmission Services are as follows:
Transmission Owner Scheduling, System Control and Dispatch Service	$	5,245,826
Other Supporting Facilities	1,149,443



	$	6,395,269

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

TRANSMISSION OF ELECTRICITY BY ISO/RTOs
Report in Column (a) the Transmission Owner receiving revenue for the transmission of electricity by the ISO/RTO. Use a separate line of data for each distinct type of transmission service involving the entities listed in Column (a). In Column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNO – Firm Network Service for Others, FNS – Firm Network Transmission Service for Self, LFP – Long-Term Firm Point-to-Point Transmission Service, OLF – Other Long-Term Firm Transmission Service, SFP – Short-Term Firm Point-to-Point Transmission Reservation, NF – Non-Firm Transmission Service, OS – Other Transmission Service and AD- Out-of-Period Adjustments. Use this code for any accounting adjustments or “true-ups” for service provided in prior reporting periods. Provide an explanation in a footnote for each adjustment. See General Instruction for definitions of codes. In column (c) identify the FERC Rate Schedule or tariff Number, on separate lines, list all FERC rate schedules or contract designations under which service, as identified in column (b) was provided. In column (d) report the revenue amounts as shown on bills or vouchers. Report in column (e) the total revenues distributed to the entity listed in column (a).
Line No.	Payment Received by (Transmission Owner Name) (a)	Statistical Classification (b)	FERC Rate Schedule or Tariff Number (c)	Total Revenue by Rate Schedule or Tariff (d)	Total Revenue (e)
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46
47
48
49
40	TOTAL

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

TRANSMISSION OF ELECTRICITY BY OTHERS (Account 565)
Report all transmission, i.e. wheeling or electricity provided by other electric utilities, cooperatives, municipalities, other public authorities, qualifying facilities, and others for the quarter. In column (a) report each company or public authority that provided transmission service. Provide the full name of the company, abbreviate if necessary, but do not truncate name or use acronyms. Explain in a footnote any ownership interest in or affiliation with the transmission service provider. Use additional columns as necessary to report all companies or public authorities that provided transmission service for the quarter reported. In column (b) enter a Statistical Classification code based on the original contractual terms and conditions of the service as follows: FNS - Firm Network Transmission Service for Self, LFP - Long-Term Firm Point-to-Point Transmission Reservations. OLF - Other Long-Term Firm Transmission Service, SFP - Short-Term Firm Point-to- Point Transmission Reservations, NF - Non-Firm Transmission Service, and OS - Other Transmission Service. See General Instructions for definitions of statistical classifications. Report in column (c) and (d) the total megawatt hours received and delivered by the provider of the transmission service. Report in column (e), (f) and (g) expenses as shown on bills or vouchers rendered to the respondent. In column (e) report the demand charges and in column (f) energy charges related to the amount of energy transferred. On column (g) report the total of all other charges on bills or vouchers rendered to the respondent, including any out of period adjustments. Explain in a footnote all components of the amount shown in column (g). Report in column (h) the total charge shown on bills rendered to the respondent. If no monetary settlement was made, enter zero in column (h). Provide a footnote explaining the nature of the non-monetary settlement, including the amount and type of energy or service rendered. Enter ""TOTAL"" in column (a) as the last line. Footnote entries and provide explanations following all required data.
			TRANSFER OF ENERGY		EXPENSES FOR TRANSMISSION OF ELECTRICITY BY OTHERS
Line No.	NameOfCompanyOrPublicAuthorityTransmissionOfElectricityByOthers Name of Company or Public Authority (Footnote Affiliations) (a)	StatisticalClassificationCode Statistical Classification (b)	TransmissionOfElectricityByOthersEnergyReceived MegaWatt Hours Received (c)	TransmissionOfElectricityByOthersEnergyDelivered MegaWatt Hours Delivered (d)	DemandChargesTransmissionOfElectricityByOthers Demand Charges ($) (e)	EnergyChargesTransmissionOfElectricityByOthers Energy Charges ($) (f)	OtherChargesTransmissionOfElectricityByOthers Other Charges ($) (g)	ChargesForTransmissionOfElectricityByOthers Total Cost of Transmission ($) (h)
1	Commonwealth Edison
2	Company of Indiana, Inc.						(a) 10,659,454	10,659,454
	TOTAL		0	0	0	0	10,659,454	10,659,454

FOOTNOTE DATA

(a) Concept: OtherChargesTransmissionOfElectricityByOthers


Commonwealth Edison Company of Indiana, Inc., a 100% owned subsidiary of the Respondent, provides transmission service to the Respondent under a service agreement.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

MISCELLANEOUS GENERAL EXPENSES (Account 930.2) (ELECTRIC)
Line No.	Description (a)	Amount (b)
1	IndustryAssociationDues Industry Association Dues	1,055,281
2	NuclearPowerResearchExpenses Nuclear Power Research Expenses
3	OtherExperimentalAndGeneralResearchExpenses Other Experimental and General Research Expenses
4	PublicationAndDistributionExpensesForSecuritiesToStockholders Pub and Dist Info to Stkhldrs...expn servicing outstanding Securities
5	OtherMiscellaneousGeneralExpenses Oth Expn greater than or equal to 5,000 show purpose, recipient, amount. Group if less than $5,000
6	Accrued Vacation Pay	1,004,146
7	Environmental remediation expenses	1,914,189
8	Other environmental expenses	67,598
9	Director's fees and expenses	598,141
10	Sale or write-off of materials and supplies	88,591
11	Bank Fees	984,069
12	Undistributed employee expenses	117,541
13	Information technology upgrades expenses	1,160,716
14	Residential Time of Use Pricing Pilot Development and Operation	521,052
15	Smart meter network professional services and other costs	524,247
16	Miscellaneous Adjustments	2,801,474
46	MiscellaneousGeneralExpenses TOTAL	10,424,781

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

Depreciation and Amortization of Electric Plant (Account 403, 404, 405)
Report in section A for the year the amounts for: (b) Depreciation Expense (Account 403); (c) Depreciation Expense for Asset Retirement Costs (Account 403.1); (d) Amortization of Limited-Term Electric Plant (Account 404); and (e) Amortization of Other Electric Plant (Account 405). Report in Section B the rates used to compute amortization charges for electric plant (Accounts 404 and 405). State the basis used to compute charges and whether any changes have been made in the basis or rates used from the preceding report year. Report all available information called for in Section C every fifth year beginning with report year 1971, reporting annually only changes to columns (c) through (g) from the complete report of the preceding year. Unless composite depreciation accounting for total depreciable plant is followed, list numerically in column (a) each plant subaccount, account or functional classification, as appropriate, to which a rate is applied. Identify at the bottom of Section C the type of plant included in any sub-account used. In column (b) report all depreciable plant balances to which rates are applied showing subtotals by functional Classifications and showing composite total. Indicate at the bottom of section C the manner in which column balances are obtained. If average balances, state the method of averaging used. For columns (c), (d), and (e) report available information for each plant subaccount, account or functional classification listed in column (a). If plant mortality studies are prepared to assist in estimating average service Lives, show in column (f) the type of mortality curve selected as most appropriate for the account and in column (g), if available, the weighted average remaining life of surviving plant. If composite depreciation accounting is used, report available information called for in columns (b) through (g) on this basis. If provisions for depreciation were made during the year in addition to depreciation provided by application of reported rates, state at the bottom of section C the amounts and nature of the provisions and the plant items to which related.
	A. Summary of Depreciation and Amortization Charges
Line No.	FunctionalClassificationAxis Functional Classification (a)	DepreciationExpenseExcludingAmortizationOfAcquisitionAdjustments Depreciation Expense (Account 403) (b)	DepreciationExpenseForAssetRetirementCostsExcludingAmortizationgOfAcquisitionAdjustments Depreciation Expense for Asset Retirement Costs (Account 403.1) (c)	AmortizationOfLimitedTermPlantOrProperty Amortization of Limited Term Electric Plant (Account 404) (d)	AmortizationOfOtherElectricPlant Amortization of Other Electric Plant (Acc 405) (e)	DepreciationAndAmortization Total (f)
1	Intangible Plant			(a) 99,413,564		99,413,564
2	Steam Production Plant
3	Nuclear Production Plant
4	Hydraulic Production Plant-Conventional
5	Hydraulic Production Plant-Pumped Storage
6	Other Production Plant
7	Transmission Plant	163,683,783	195,202	92,854		163,971,839
8	Distribution Plant	720,489,035	1,396,949	197,459		722,083,443
9	Regional Transmission and Market Operation
10	General Plant	121,879,988	266,772	956,284		(b) 123,103,044
11	Common Plant-Electric
12	TOTAL	1,006,052,806	1,858,923	100,660,161		1,108,571,890

B. Basis for Amortization Charges
See footnote data for Page 336, Line No. 1, Column (d) for required information.

	C. Factors Used in Estimating Depreciation Charges
Line No.	AccountNumberFactorsUsedInEstimatingDepreciationCharges Account No. (a)	DepreciablePlantBase Depreciable Plant Base (in Thousands) (b)	UtilityPlantEstimatedAverageServiceLife Estimated Avg. Service Life (c)	UtilityPlantNetSalvageValuePercentage Net Salvage (Percent) (d)	UtilityPlantAppliedDepreciationRate Applied Depr. Rates (Percent) (e)	MortalityCurveType Mortality Curve Type (f)	UtilityPlantWeightedAverageRemainingLife Average Remaining Life (g)
12	(c) Transmission-	6,579,016	63 years	44	(e) 2.53		47 years, 8 months, 50 days
13	Distribution-
14	Excl HVD,Transf&Meters	18,759,702	54 years	46	(f) 2.75		43 years, 3 months, 10 days
15	High Voltage Distribution	4,112,684	59 years	38	(g) 2.5		44 years, 5 months, 14 days
16	Line Transformers	1,604,152	35 years		2.33	SQ	22 years, 3 months, 19 days
17	Non AMI Meters	1,006	0 years				0 years
18	AMI Meters	794,275	15 years	15	7.87	SQ	9 years, 6 months
19	Meters Other (Relay/CT/PT, etc.)	55,801	35 years	10	3.29	SQ	24 years, 3 months, 19 days
20	General Plant-
21	Structures & Improvements	778,676	50 years	20	2.6	R1	41 years, 6 months
22	Computer Equipment	118,827	5 years		19.99	SQ	2 years, 10 months, 25 days
23	Furniture & Equipment	41,839	15 years		6.67	SQ	9 years, 10 months, 25 days
24	Office Machines	421	10 years		10	SQ	5 years
25	Transportation:
26	Passenger Cars	2,689	8 years	10	10.92	R3	3 years, 10 months, 25 days
27	Tractor Trailers	1,087	15 years	10	1.24	R2.5	3 years, 2 months, 13 days
28	Trailers	23,965	18 years	15	4.41	S0	13 years, 6 months
29	Light-duty Trucks	92,168	10 years	10	7.45	R1.5	6 years
30	Heavy-duty Trucks	350,638	14 years	10	5.86	S1.5	9 years, 2 months, 13 days
31	Stores Equipment	8,264	15 years		6.67	SQ	10 years, 1 month, 5 days
32	Tools, Shop & Garage Equipment	277,734	25 years		4	SQ	14 years, 8 months, 13 days
33	Laboratory Equipment	17,479	15 years		6.67	SQ	11 years, 7 months, 5 days
34	Power Operated Equipment	7,792	15 years	5	6.63	L3	6 years, 7 months, 5 days
35	Communications Equipment	252,152	15 years	10	7.33	SQ	9 years, 4 months, 25 days
36	MESH Communications Equipment	179,829	10 years	10	11	SQ	5 years, 1 month, 5 days
37	SCADA, Fiber, Microwave Comm Equip	771,710	20 years	10	2.27	L2	14 years, 3 months, 19 days
38	Smart Street Lights Comm Equip	44	12 years	10	9.17	SQ	6 years, 6 months
39	(d) Miscellaneous Equipment	22,529	15 years		6.67	SQ	10 years, 8 months, 50 days
40	General Notes

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: AmortizationOfLimitedTermPlantOrProperty

The amortization charges shown in Column (d), Line 1 - Intangible Plant represent the straight-line amortization of the development costs of the following software:

System

Avg Remaining Life in Years

CTA PHI Systems

Maint Inspect SW

Oracle Upgrade SW

ComEd Care Ctr SW

Voltage Assessment

LED Streetlights SW

BIDA Smrt Enrgy EOL

Fusion SW

Common MDM

BIDA Customer Proj

BIDA SESII Enhance

Robotic Process SW

Digital Strgy Epay

EU North Star RE

CIS Transformation

EU Custon Analytic

ISUM 2020 SW

EMS Implementation

BIDA AMI

GIS

EU SW Electric

Grid FR

Misc Comp Software FR

SES

BIDA Grid EOL

Mobile App

IVR Convergence

EU Dig Prgm: Web

Port Mgmt Tool

SAM SW

UI Plan SW

*Fully amortized during 2023.

The amortization charges shown in Column (d), Line 1 - Intangible Plant, represent the straight line amortization of the development costs related to software. See note for Column (d) line 1 for additional details regarding the system software included in Intangible Plant. Note that software is typically amortized over a 5 year period unless another life is deemed more appropriate.

The amortization charges shown in Column (d), Line 7 and Line 8 represent the amortization of costs for three Transmission Right-of Way Easements and two Distribution Right-of Way Easement, respectively, based on the periods covered by the Easements.

The amortization charges shown in Column (d), Line 10 - General Plant represent the amortization of three leasehold improvements over the lives of the respective leases.

(b) Concept: DepreciationAndAmortization


The amount of depreciation expense associated with Account 397 (Communication Equipment) for the year 2023 is $57,606,472.21 - 28.56% of such amount is directly assignable to the Transmission function.


This note pertains to all plant accounts on Page 337 in Column (a), excluding transportation. Depreciation is computed monthly by taking the monthly depreciation rate times the average depreciable plant-in-service balances at the beginning and end of each month. The amounts shown in Column (b) are the annual average depreciable plan-in-service balances computed by dividing the sum of the monthly average plant-in-service balances for the year by twelve.

(d) Concept: AccountNumberFactorsUsedInEstimatingDepreciationCharges


General Notes for Page 337: Page 337, Section C excludes all amortized Limited Term Plant (software, leasehold improvements, right of ways, etc.) as referenced in the footnote for Page 336, Line No. 1, Column (d). The Company provides depreciation on a straight-line basis by amortizing the cost of depreciable electric plant-in-service over estimated service lives for each class of plant. The annual average depreciable plant base for [a] Transmission, [b] Distribution - excluding HVD, Line Transformers and Meters, [c] Distribution High Voltage is reduced by $16,454,447, $49,180,967 and $21,065,181, respectively, related to estimated unrecorded retirements of certain plant-in-service.

(e) Concept: UtilityPlantAppliedDepreciationRate


A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

(f) Concept: UtilityPlantAppliedDepreciationRate


A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

(g) Concept: UtilityPlantAppliedDepreciationRate


A composite rate is calculated for all depreciation groups; therefore, an individual mortality curve is not available.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

REGULATORY COMMISSION EXPENSES
Report particulars (details) of regulatory commission expenses incurred during the current year (or incurred in previous years, if being amortized) relating to format cases before a regulatory body, or cases in which such a body was a party. Report in columns (b) and (c), only the current year's expenses that are not deferred and the current year's amortization of amounts deferred in previous years. Show in column (k) any expenses incurred in prior years which are being amortized. List in column (a) the period of amortization. List in columns (f), (g), and (h), expenses incurred during the year which were charged currently to income, plant, or other accounts. Minor items (less than $25,000) may be grouped.
						EXPENSES INCURRED DURING YEAR				AMORTIZED DURING YEAR
						CURRENTLY CHARGED TO
Line No.	RegulatoryCommissionDescription Description (Furnish name of regulatory commission or body the docket or case number and a description of the case) (a)	RegulatoryExpensesAssessedByRegulatoryCommission Assessed by Regulatory Commission (b)	RegulatoryExpensesOfUtility Expenses of Utility (c)	RegulatoryCommissionExpensesAmount Total Expenses for Current Year (b) + (c) (d)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 at Beginning of Year (e)	NameOfDepartmentRegulatoryCommissionExpensesCharged Department (f)	AccountNumberRegulatoryCommissionExpensesCharged Account No. (g)	RegulatoryComissionExpensesIncurredAndCharged Amount (h)	RegulatoryCommissionExpensesDeferredToOtherRegulatoryAssets Deferred to Account 182.3 (i)	DeferredRegulatoryCommissionExpensesAmortizedInContraAccount Contra Account (j)	DeferredRegulatoryCommissionExpensesAmortized Amount (k)	OtherRegulatoryAssetsRegulatoryCommissionExpenses Deferred in Account 182.3 End of Year (l)
1	Illinois Commerce Commission
2	-------------------------------------
3	Docket Nos. -
4	19-0875, 19-0940, 19-1064, 20-0627, 20-0703, 20-0629
5	21-0160, 21-0416, 21-0530, 21-0546, 21-0544, 21-0761
6	21-0777, 22-0769, 22-0727, 22-0424, 22-0160, 22-0076
7	23-0834, 23-0826, 23-0770, 23-0743, 23-0744, 23-0734,
8	23-0731, 23-0722, 23-0710, 23-0675, 23-0622, 23-0610,
9	23-0675, 23-0622, 23-0610, 23-0592, 23-0574, 23-0553
10	23-0503, 23-0504, 23-0476, 23-0444, 23-0407, 23-0381
11	23-0355, 23-0341, 23-0269, 23-0197, 23-0592
12	Various complaint and petition matters		144,000	144,000			928	144,000
13	Docket No. 23-0345 Annual Formula rate update and revenue
14	requirement reconciliation		331,147	331,147			928	331,147
15	Docket No. 22-0067 Performance Metrics		75,200	75,200			928	75,200
16	Docket No. docket anticipated Equitable Energy Upgrade Program		36,400	36,400			928	36,400
17	Docket No. docket anticipated Low Income Rate Study		404,731	404,731			928	404,731
18	Docket No. docket anticipated Value of DER Proceeding		29,666	29,666			928	29,666
19	Docket No. 23-0055 Verified Petition for Approval
20	of a Multi-Year Rate Plan		3,627,673	3,627,673	2,160,188		928	6,823,599	5,128,081		2,067,098	5,221,171
21	Annual Ethics & Compliance Fee		500,000	500,000			928	500,000
22	Various ICC dockets		164,739	164,739			928	164,739
23	Federal Energy Regulatory Commission
24	Docket No. FA21-5-000 - FERC Audit		657,470	657,470			928	657,470
25	Various FERC dockets		57,307	57,307			928	57,307
46	TOTAL		6,028,333	6,028,333	2,160,188			9,224,259	5,128,081		2,067,098	5,221,171

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

RESEARCH, DEVELOPMENT, AND DEMONSTRATION ACTIVITIES
Describe and show below costs incurred and accounts charged during the year for technological research, development, and demonstration (R, D and D) project initiated, continued or concluded during the year. Report also support given to others during the year for jointly-sponsored projects.(Identify recipient regardless of affiliation.) For any R, D and D work carried with others, show separately the respondent's cost for the year and cost chargeable to others (See definition of research, development, and demonstration in Uniform System of Accounts). Indicate in column (a) the applicable classification, as shown below: Classifications: Electric R, D and D Performed Internally: Generation hydroelectric Recreation fish and wildlife Other hydroelectric Fossil-fuel steam Internal combustion or gas turbine Nuclear Unconventional generation Siting and heat rejection Transmission Overhead Underground Distribution Regional Transmission and Market Operation Environment (other than equipment) Other (Classify and include items in excess of $50,000.) Total Cost Incurred Electric, R, D and D Performed Externally: Research Support to the electrical Research Council or the Electric Power Research Institute Research Support to Edison Electric Institute Research Support to Nuclear Power Groups Research Support to Others (Classify) Total Cost Incurred Include in column (c) all R, D and D items performed internally and in column (d) those items performed outside the company costing $50,000 or more, briefly describing the specific area of R, D and D (such as safety, corrosion control, pollution, automation, measurement, insulation, type of appliance, etc.). Group items under $50,000 by classifications and indicate the number of items grouped. Under Other, (A (6) and B (4)) classify items by type of R, D and D activity. Show in column (e) the account number charged with expenses during the year or the account to which amounts were capitalized during the year, listing Account 107, Construction Work in Progress, first. Show in column (f) the amounts related to the account charged in column (e). Show in column (g) the total unamortized accumulating of costs of projects. This total must equal the balance in Account 188, Research, Development, and Demonstration Expenditures, Outstanding at the end of the year. If costs have not been segregated for R, D and D activities or projects, submit estimates for columns (c), (d), and (f) with such amounts identified by ""Est."" Report separately research and related testing facilities operated by the respondent.
					AMOUNTS CHARGED IN CURRENT YEAR
Line No.	ResearchDevelopmentAndDemonstrationClassification Classification (a)	ResearchDevelopmentAndDemonstrationDescription Description (b)	ResearchDevelopmentAndDemonstrationCostsIncurredInternally Costs Incurred Internally Current Year (c)	ResearchDevelopmentAndDemonstrationCostsIncurredExternally Costs Incurred Externally Current Year (d)	AccountNumberForResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Account (e)	ResearchDevelopmentAndDemonstrationCosts Amounts Charged In Current Year: Amount (f)	ResearchDevelopmentAndDemonstrationExpenditures Unamortized Accumulation (g)
1	B-1	EPRI Selected Programs		598,582	566	598,582
2	B-1	EPRI Selected Programs		567,084	588	567,084
3	B-2	CEA Technologies Inc. Program		105,881	566	105,881
4	B-2	CEA Technologies Inc. Program		9,786	588	9,786
5	B-2	National Electric Energy Testing, Research and
6	B-2	Application Center		33,416	566	33,416
7	B-2	Application Center		34,780	588	34,780
8	B-2	Watson & Renner		16,688	566	16,688
9	B-2	Watson & Renner		16,688	588	16,688
10	B-2	CIGRE		2,500	566	2,500
11	B-2	CIGRE		2,500	588	2,500
12	Total			1,387,905		1,387,905

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

DISTRIBUTION OF SALARIES AND WAGES
Report below the distribution of total salaries and wages for the year. Segregate amounts originally charged to clearing accounts to Utility Departments, Construction, Plant Removals, and Other Accounts, and enter such amounts in the appropriate lines and columns provided. In determining this segregation of salaries and wages originally charged to clearing accounts, a method of approximation giving substantially correct results may be used.
Line No.	Classification (a)	Direct Payroll Distribution (b)	Allocation of Payroll Charged for Clearing Accounts (c)	Total (d)
1	SalariesAndWagesElectricAbstract Electric
2	SalariesAndWagesElectricOperationAbstract Operation
3	SalariesAndWagesElectricOperationProduction Production	1,234,649
4	SalariesAndWagesElectricOperationTransmission Transmission	27,875,117
5	SalariesAndWagesElectricOperationRegionalMarket Regional Market
6	SalariesAndWagesElectricOperationDistribution Distribution	67,138,139
7	SalariesAndWagesElectricOperationCustomerAccounts Customer Accounts	103,137,544
8	SalariesAndWagesElectricOperationCustomerServiceAndInformational Customer Service and Informational	4,219,332
9	SalariesAndWagesElectricOperationSales Sales
10	SalariesAndWagesElectricOperationAdministrativeAndGeneral Administrative and General	54,573,222
11	SalariesAndWagesElectricOperation TOTAL Operation (Enter Total of lines 3 thru 10)	258,178,003
12	SalariesAndWagesElectricMaintenanceAbstract Maintenance
13	SalariesAndWagesElectricMaintenanceProduction Production
14	SalariesAndWagesElectricMaintenanceTransmission Transmission	23,153,242
15	SalariesAndWagesElectricMaintenanceRegionalMarket Regional Market
16	SalariesAndWagesElectricMaintenanceDistribution Distribution	96,515,666
17	SalariesAndWagesElectricMaintenanceAdministrativeAndGeneral Administrative and General	3,645,985
18	SalariesAndWagesElectricMaintenance TOTAL Maintenance (Total of lines 13 thru 17)	123,314,893
19	SalariesAndWagesElectricOperationAndMaintenanceAbstract Total Operation and Maintenance
20	SalariesAndWagesElectricProduction Production (Enter Total of lines 3 and 13)	1,234,649
21	SalariesAndWagesElectricTransmission Transmission (Enter Total of lines 4 and 14)	51,028,359
22	SalariesAndWagesElectricRegionalMarket Regional Market (Enter Total of Lines 5 and 15)
23	SalariesAndWagesElectricDistribution Distribution (Enter Total of lines 6 and 16)	163,653,805
24	SalariesAndWagesElectricCustomerAccounts Customer Accounts (Transcribe from line 7)	103,137,544
25	SalariesAndWagesElectricCustomerServiceAndInformational Customer Service and Informational (Transcribe from line 8)	4,219,332
26	SalariesAndWagesElectricSales Sales (Transcribe from line 9)
27	SalariesAndWagesElectricAdministrativeAndGeneral Administrative and General (Enter Total of lines 10 and 17)	58,219,207
28	SalariesAndWagesElectricOperationAndMaintenance TOTAL Oper. and Maint. (Total of lines 20 thru 27)	381,492,896	45,237,606	426,730,502
29	SalariesAndWagesGasAbstract Gas
30	SalariesAndWagesGasOperationAbstract Operation
31	SalariesAndWagesGasOperationProductionManufacturedGas Production - Manufactured Gas
32	SalariesAndWagesGasOperationProductionNaturalGas Production-Nat. Gas (Including Expl. And Dev.)
33	SalariesAndWagesGasOperationOtherGasSupply Other Gas Supply
34	SalariesAndWagesGasOperationStorageLiquifiedNaturalGasTerminalingAndProcessing Storage, LNG Terminaling and Processing
35	SalariesAndWagesGasOperationTransmission Transmission
36	SalariesAndWagesGasOperationDistribution Distribution
37	SalariesAndWagesGasCustomerAccounts Customer Accounts
38	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational
39	SalariesAndWagesGasSales Sales
40	SalariesAndWagesGasOperationAdministrativeAndGeneral Administrative and General
41	SalariesAndWagesGasOperation TOTAL Operation (Enter Total of lines 31 thru 40)
42	SalariesAndWagesGasMaintenanceAbstract Maintenance
43	SalariesAndWagesGasMaintenanceProductionManufacturedGas Production - Manufactured Gas
44	SalariesAndWagesGasMaintenanceProductionNaturalGas Production-Natural Gas (Including Exploration and Development)
45	SalariesAndWagesGasMaintenanceOtherGasSupply Other Gas Supply
46	SalariesAndWagesGasMaintenanceStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing
47	SalariesAndWagesGasMaintenanceTransmission Transmission
48	SalariesAndWagesGasMaintenanceDistribution Distribution
49	SalariesAndWagesGasMaintenanceAdministrativeAndGeneral Administrative and General
50	SalariesAndWagesGasMaintenance TOTAL Maint. (Enter Total of lines 43 thru 49)
51	SalariesAndWagesGasOperationAndMaintenanceAbstract Total Operation and Maintenance
52	SalariesAndWagesGasProductionManufacturedGas Production-Manufactured Gas (Enter Total of lines 31 and 43)
53	SalariesAndWagesGasProductionNaturalGas Production-Natural Gas (Including Expl. and Dev.) (Total lines 32,
54	SalariesAndWagesGasOtherGasSupply Other Gas Supply (Enter Total of lines 33 and 45)
55	SalariesAndWagesGasStorageLngTerminalingAndProcessing Storage, LNG Terminaling and Processing (Total of lines 31 thru
56	SalariesAndWagesGasTransmission Transmission (Lines 35 and 47)
57	SalariesAndWagesGasDistribution Distribution (Lines 36 and 48)
58	SalariesAndWagesGasCustomerAccounts Customer Accounts (Line 37)
59	SalariesAndWagesGasCustomerServiceAndInformational Customer Service and Informational (Line 38)
60	SalariesAndWagesGasSales Sales (Line 39)
61	SalariesAndWagesGasAdministrativeAndGeneral Administrative and General (Lines 40 and 49)
62	SalariesAndWagesGasOperationAndMaintenance TOTAL Operation and Maint. (Total of lines 52 thru 61)
63	SalariesAndWagesOtherUtilityDepartmentsAbstract Other Utility Departments
64	SalariesAndWagesOtherUtilityDepartmentsOperationAndMaintenance Operation and Maintenance
65	SalariesAndWagesOperationsAndMaintenance TOTAL All Utility Dept. (Total of lines 28, 62, and 64)	381,492,896	45,237,606	426,730,502
66	SalariesAndWagesUtilityPlantAbstract Utility Plant
67	SalariesAndWagesUtilityPlantConstructionAbstract Construction (By Utility Departments)
68	SalariesAndWagesUtilityPlantConstructionElectricPlant Electric Plant	409,163,958	211,677,087	620,841,045
69	SalariesAndWagesUtilityPlantConstructionGasPlant Gas Plant
70	SalariesAndWagesUtilityPlantConstructionOther Other (provide details in footnote):
71	SalariesAndWagesUtilityPlantConstruction TOTAL Construction (Total of lines 68 thru 70)	409,163,958	211,677,087	620,841,045
72	SalariesAndWagesPlantRemovalAbstract Plant Removal (By Utility Departments)
73	SalariesAndWagesPlantRemovalElectricPlant Electric Plant	45,174,325	20,277,200	65,451,525
74	SalariesAndWagesPlantRemovalGasPlant Gas Plant
75	SalariesAndWagesPlantRemovalOther Other (provide details in footnote):
76	SalariesAndWagesPlantRemoval TOTAL Plant Removal (Total of lines 73 thru 75)	45,174,325	20,277,200	65,451,525
77	SalariesAndWagesOtherAccountsAbstract Other Accounts (Specify, provide details in footnote):
78	SalariesAndWagesOtherAccountsDescription Other Accounts (Specify, provide details in footnote):
79	SalariesAndWagesOtherAccountsDescription Stores Expense Undistributed	21,569,489	21,569,489
80	SalariesAndWagesOtherAccountsDescription Clearing Accounts	77,434,410	77,434,410
81	SalariesAndWagesOtherAccountsDescription Miscellaneous	(a) 21,057,027		21,057,027
82	SalariesAndWagesOtherAccountsDescription
83	SalariesAndWagesOtherAccountsDescription
84	SalariesAndWagesOtherAccountsDescription
85	SalariesAndWagesOtherAccountsDescription
86	SalariesAndWagesOtherAccountsDescription
87	SalariesAndWagesOtherAccountsDescription
88	SalariesAndWagesOtherAccountsDescription
89	SalariesAndWagesOtherAccountsDescription
90	SalariesAndWagesOtherAccountsDescription
91	SalariesAndWagesOtherAccountsDescription
92	SalariesAndWagesOtherAccountsDescription
93	SalariesAndWagesOtherAccountsDescription
94	SalariesAndWagesOtherAccountsDescription
95	SalariesAndWagesOtherAccounts TOTAL Other Accounts	120,060,926	99,003,899	21,057,027
96	SalariesAndWagesGeneralExpense TOTAL SALARIES AND WAGES	955,892,105	178,187,994	1,134,080,099

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: SalariesAndWagesOtherAccounts


Includes direct labor charges related to non-utility operations.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

COMMON UTILITY PLANT AND EXPENSES
Describe the property carried in the utility's accounts as common utility plant and show the book cost of such plant at end of year classified by accounts as provided by Electric Plant Instruction 13, Common Utility Plant, of the Uniform System of Accounts. Also show the allocation of such plant costs to the respective departments using the common utility plant and explain the basis of allocation used, giving the allocation factors. Furnish the accumulated provisions for depreciation and amortization at end of year, showing the amounts and classifications of such accumulated provisions, and amounts allocated to utility departments using the common utility plant to which such accumulated provisions relate, including explanation of basis of allocation and factors used. Give for the year the expenses of operation, maintenance, rents, depreciation, and amortization for common utility plant classified by accounts as provided by the Uniform System of Accounts. Show the allocation of such expenses to the departments using the common utility plant to which such expenses are related. Explain the basis of allocation used and give the factors of allocation. Give date of approval by the Commission for use of the common utility plant classification and reference to the order of the Commission or other authorization.

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

AMOUNTS INCLUDED IN ISO/RTO SETTLEMENT STATEMENTS
The respondent shall report below the details called for concerning amounts it recorded in Account 555, Purchase Power, and Account 447, Sales for Resale, for items shown on ISO/RTO Settlement Statements. Transactions should be separately netted for each ISO/RTO administered energy market for purposes of determining whether an entity is a net seller or purchaser in a given hour. Net megawatt hours are to be used as the basis for determining whether a net purchase or sale has occurred. In each monthly reporting period, the hourly sale and purchase net amounts are to be aggregated and separately reported in Account 447, Sales for Resale, or Account 555, Purchased Power, respectively.
Line No.	Description of Item(s) (a)	Balance at End of Quarter 1 (b)	Balance at End of Quarter 2 (c)	Balance at End of Quarter 3 (d)	Balance at End of Year (e)
1	Energy
2	Net Purchases (Account 555)	127,214,630	268,625,245	531,499,783	(a) 691,537,366
2.1	Net Purchases (Account 555.1)
3	Net Sales (Account 447)	5,105,563	8,876,943	22,944,367	27,394,838
4	Transmission Rights
5	Ancillary Services	6,933,165	16,209,887	27,796,060	(b) 38,170,444
6	Other Items (list separately)
7
8
9
10
11
12
13
14
15
16
17
18
19
20
21
22
23
24
25
26
27
28
29
30
31
32
33
34
35
36
37
38
39
40
41
42
43
44
45
46	TOTAL	139,253,358	293,712,075	582,240,210	757,102,648

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: IsoOrRtoSettlementsEnergyNetPurchasesPurchasedPower


Amounts reported in Line Nos. 2, 3 & 5 reflect the year-to-date activities through the end of the applicable quarter.

(b) Concept: IsoOrRtoSettlementsAncillaryServices


Purchases and sales of ancillary services were recorded in the following accounts:

Purchases
Account 555	$	38,534,112
Account 561.4	14,332,388
Account 561.8	684,154
Account 575.7	6,841,513
Sales
Account 456.1	(22,221,723)
Total	$	38,170,444

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

PURCHASES AND SALES OF ANCILLARY SERVICES
Report the amounts for each type of ancillary service shown in column (a) for the year as specified in Order No. 888 and defined in the respondents Open Access Transmission Tariff. In columns for usage, report usage-related billing determinant and the unit of measure. On Line 1 columns (b), (c), (d), and (e) report the amount of ancillary services purchased and sold during the year. On Line 2 columns (b), (c), (d), and (e) report the amount of reactive supply and voltage control services purchased and sold during the year. On Line 3 columns (b), (c), (d), and (e) report the amount of regulation and frequency response services purchased and sold during the year. On Line 4 columns (b), (c), (d), and (e) report the amount of energy imbalance services purchased and sold during the year. On Lines 5 and 6, columns (b), (c), (d), and (e) report the amount of operating reserve spinning and supplement services purchased and sold during the period. On Line 7 columns (b), (c), (d), and (e) report the total amount of all other types ancillary services purchased or sold during the year. Include in a footnote and specify the amount for each type of other ancillary service provided.
		Amount Purchased for the Year			Amount Sold for the Year
		Usage - Related Billing Determinant			Usage - Related Billing Determinant
Line No.	Type of Ancillary Service (a)	Number of Units (b)	Unit of Measure (c)	Dollar (d)	Number of Units (e)	Unit of Measure (f)	Dollars (g)
1	Scheduling, System Control and Dispatch	32,176,037	MWH	20,309,969	91,236,639	MWH	(a) 22,221,723
2	Reactive Supply and Voltage			(b) 23,325,901
3	Regulation and Frequency Response			(c) 5,371,217
4	Energy Imbalance
5	Operating Reserve - Spinning			(d) 2,761,637
6	Operating Reserve - Supplement			(e) 2,962,446
7	Other			(f) 5,660,997
8	Total (Lines 1 thru 7)	32,176,037		60,392,167	91,236,639		22,221,723

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: AncillaryServicesSoldAmount


Represents revenues allocated to the respondent from PJM Interconnection, LLC.

(b) Concept: AncillaryServicesPurchasedAmount


Represents the per load ratio share.


This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,176,037.

(d) Concept: AncillaryServicesPurchasedAmount


This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,176,037.

(e) Concept: AncillaryServicesPurchasedAmount


This footnote applies to the cells in lines 3, 5, and 6, column d. The number of units applicable to Line No. 3, Column (b) is 32,176,037.

(f) Concept: AncillaryServicesPurchasedAmount


The details of this "Other" amount are as follows:

Black Start service charge	$	4,171,292
Schedule 10 - NERC charges	620,322
Schedule 10 - RFC charges	896,247
Reconciliation of Schedule 10 charges	12,387
Consumer Advocates of PJM States, Inc. (CAPS)	19,130
Fuel Cost Policy Penalty	(58,381)
	$	5,660,997

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

MONTHLY TRANSMISSION SYSTEM PEAK LOAD
Report the monthly peak load on the respondent's transmission system. If the respondent has two or more power systems which are not physically integrated, furnish the required information for each non-integrated system. Report on Column (b) by month the transmission system's peak load. Report on Columns (c ) and (d) the specified information for each monthly transmission - system peak load reported on Column (b). Report on Columns (e) through (j) by month the system' monthly maximum megawatt load by statistical classifications. See General Instruction for the definition of each statistical classification.
Line No.	Month (a)	Monthly Peak MW - Total (b)	Day of Monthly Peak (c)	Hour of Monthly Peak (d)	Firm Network Service for Self (e)	Firm Network Service for Others (f)	Long-Term Firm Point-to-point Reservations (g)	Other Long-Term Firm Service (h)	Short-Term Firm Point-to-point Reservation (i)	Other Service (j)
	NAME OF SYSTEM: 0
1	January	13,658	31	(a) 18	5,464	8,194
2	February	13,392	3	(b) 18	5,329	8,063
3	March	11,931	14	(c) 7	4,094	7,837
4	Total for Quarter 1				14,887	24,094	0	0	0	0
5	April	11,698	13	(d) 17	4,129	7,569
6	May	15,598	31	(e) 13	6,122	9,476
7	June	16,786	30	(f) 13	7,059	9,727
8	Total for Quarter 2				17,310	26,772	0	0	0	0
9	July	19,358	27	(g) 16	8,975	10,383
10	August	22,467	24	(h) 16	10,786	11,681
11	September	18,322	5	(i) 13	7,775	10,547
12	Total for Quarter 3				27,536	32,611	0	0	0	0
13	October	14,968	3	(j) 16	5,979	8,989
14	November	13,096	28	(k) 17	4,985	8,111
15	December	12,949	18	(l) 17	4,888	8,061
16	Total for Quarter 4				15,852	25,161	0	0	0	0
17	Total				75,585	108,638	0	0	0	0

Name of Respondent:

Commonwealth Edison Company

This report is:

(1)

☑ An Original

(2)

☐ A Resubmission

Date of Report:

12/31/2023

Year/Period of Report

End of:

2023

FOOTNOTE DATA

(a) Concept: HourOfMonthlyPeakExcludingIsoAndRto